Clearway Energy (CWEN) 10-Q 4 Nov 16 2016 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2016	Oct. 31, 2016
Document And Entity Information [Abstract]
Entity Registrant Name	NRG Yield, Inc.
Entity Central Index Key	1,567,683
Document Type	10-Q
Document Period End Date	Sep. 30, 2016
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Voluntary Filers	No
Entity Well-known Seasoned Issuer	Yes
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Common Class A [Member]
Class of Stock
Entity Common Stock, Shares Outstanding		34,586,250
Common Class B [Member]
Class of Stock
Entity Common Stock, Shares Outstanding		42,738,750
Common Class C [Member]
Class of Stock
Entity Common Stock, Shares Outstanding		62,784,250
Common Class D [Member]
Class of Stock
Entity Common Stock, Shares Outstanding		42,738,750

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Millions, $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015		Sep. 30, 2016	Sep. 30, 2015
Operating Revenues
Total operating revenues		$ 272	$ 256	[1],[2]	$ 789	$ 729	[1],[2]
Operating Costs and Expenses
Cost of operations		76	82	[1]	238	246	[1]
Depreciation and amortization		75	69	[1],[2]	224	222	[1],[2]
General and administrative		4	3	[1],[2]	10	9	[1],[2]
Acquisition-related transaction and integration costs		0	1	[1],[2]	0	2	[1],[2]
Total operating costs and expenses		155	155	[1]	472	479	[1]
Operating Income		117	101	[1],[2]	317	250	[1],[2]
Other Income (Expense)
Equity in earnings of unconsolidated affiliates		13	12	[1],[2]	29	19	[1],[2]
Other income, net		1	0	[1]	3	2	[1],[2]
Loss on debt extinguishment		0	(2)	[1],[2]	0	(9)	[1],[2],[3]
Interest expense		(71)	(71)	[1],[2]	(213)	(201)	[1],[2]
Total other expense, net		(57)	(61)	[1]	(181)	(189)	[1]
Income Before Income Taxes		60	40	[1],[2]	136	61	[1],[2]
Income tax expense		13	8	[2]	25	8	[2]
Net Income		47	32	[1],[2],[4]	111	53	[1],[2],[4]
Less: Pre-acquisition net income (loss) of Drop Down Assets		6	(2)	[4]	10	(6)	[1],[4]
Net Income Excluding Pre-acquisition Net Income (Loss) of Drop Down Assets		41	34	[1]	101	59	[1]
Less: Net income attributable to noncontrolling interests		8	17	[1]	31	37	[1]
Net Income Attributable to NRG Yield, Inc.		33	17		70	22
Common Class C [Member]
Other Income (Expense)
Net Income Attributable to NRG Yield, Inc.	[5]	$ 21	$ 11		$ 45	$ 12
Earnings Per Share Attributable to NRG Yield, Inc. Class A and Class C Common Stockholders
Weighted average number of common shares outstanding — basic	[5]	63	63		63	44
Weighted average number of common shares outstanding — diluted	[5]	73	63		63	44
Earnings per weighted average common share — basic	[5]	$ 0.34	$ 0.18		$ 0.72	$ 0.28
Earnings per weighted average common share — diluted	[5]	0.32	0.18		0.72	0.28
Dividends Per Common Share, Cash Paid		$ 0.24	$ 0.21		$ 0.695	$ 0.41
Common Class A [Member]
Other Income (Expense)
Net Income Attributable to NRG Yield, Inc.	[5]	$ 12	$ 6		$ 25	$ 10
Earnings Per Share Attributable to NRG Yield, Inc. Class A and Class C Common Stockholders
Weighted average number of common shares outstanding — basic	[5]	35	35		35	35
Weighted average number of common shares outstanding — diluted	[5]	49	35		49	35
Earnings per weighted average common share — basic	[5]	$ 0.34	$ 0.18		$ 0.72	$ 0.28
Earnings per weighted average common share — diluted	[5]	0.30	0.18		0.68	0.28
Dividends Per Common Share, Cash Paid		$ 0.24	$ 0.21		$ 0.695	$ 0.80
[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[3]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[4]	a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[5]	(a) Net income attributable to NRG Yield, Inc. and basic and diluted earnings per share might not recalculate due to presenting values in millions rather than whole dollars.

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Loss - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015		Sep. 30, 2016	Sep. 30, 2015
Net income	$ 47	$ 32	[1],[2],[3]	$ 111	$ 53	[1],[2],[3]
Other Comprehensive Income (Loss), net of tax
Unrealized gain (loss) on derivatives, net of income tax benefit of $1, $9, $13 and $13	21	(31)	[3]	(36)	(28)	[3]
Other comprehensive income (loss)	21	(31)	[3]	(36)	(28)	[3]
Comprehensive Income	68	1	[3]	75	25	[3]
Less: Pre-acquisition net income (loss) of Drop Down Assets	6	(2)	[3]	10	(6)	[1],[3]
Less: Comprehensive income attributable to noncontrolling interests	30	2		16	32
Comprehensive Income (Loss) Attributable to NRG Yield, Inc.	$ 32	$ 1		$ 49	$ (1)
[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[3]	a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Consolidated Statements of Com4

Consolidated Statements of Comprehensive Loss (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Statement of Comprehensive Income [Abstract]
Unrealized gain/loss on derivatives, income tax expense /(benefit)	$ (1)	$ (9)	$ (13)	$ (13)

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Current Assets
Cash and cash equivalents	$ 200	$ 111
Restricted cash	138	131
Accounts receivable — trade	115	101
Accounts receivable — affiliate	2	0
Inventory	37	36
Derivative instruments	1	0
Notes receivable	17	17
Prepayments and other current assets	21	20
Total current assets	531	416
Property, plant and equipment, net	5,711	5,878
Other Assets
Equity investments in affiliates	690	697
Notes receivable	18	30
Intangible assets, net of accumulated amortization of $151 and $93	1,303	1,362
Deferred income taxes	182	170
Other non-current assets	47	136
Total other assets	2,240	2,395
Total Assets	8,482	8,689
Current Liabilities
Current portion of long-term debt	281	264
Accounts payable — trade	23	23
Accounts payable — affiliate	29	86
Derivative instruments	32	39
Accrued expenses and other current liabilities	94	77
Total current liabilities	459	489
Other Liabilities
Long-term debt	5,359	5,329
Accounts payable — affiliate	11	0
Derivative instruments	107	61
Other non-current liabilities	78	72
Total non-current liabilities	5,555	5,462
Total Liabilities	6,014	5,951
Stockholders' Equity
Preferred stock, $0.01 par value; 10,000,000 shares authorized; none issued	0	0
Class A, Class B, Class C and Class D common stock, $0.01 par value; 3,000,000,000 shares authorized (Class A 500,000,000, Class B 500,000,000, Class C 1,000,000,000, Class D 1,000,000,000); 182,848,000 shares issued and outstanding (Class A 34,586,250, Class B 42,738,750, Class C 62,784,250, Class D 42,738,750) at September 30, 2016, and December 31, 2015	1	1
Additional paid-in capital	1,858	1,855
Retained earnings	35	12
Accumulated other comprehensive loss	(48)	(27)
Noncontrolling interest	622	897
Total Stockholders' Equity	2,468	2,738
Total Liabilities and Stockholders' Equity	$ 8,482	$ 8,689

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Sep. 30, 2016	Dec. 31, 2015
Preferred Stock, Shares Authorized	10,000,000	10,000,000
Preferred Stock, Shares Issued	0	0
Common Class A [Member]
Common Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Common Stock, Shares Authorized	500,000,000	500,000,000
Common Stock, Shares, Issued	34,586,250	34,586,250
Preferred Stock [Member]
Preferred Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Common Class B [Member]
Common Stock, Shares Authorized	500,000,000	500,000,000
Common Stock, Shares, Issued	42,738,750	42,738,750
Common Class C [Member]
Common Stock, Shares Authorized	500,000,000	500,000,000
Common Stock, Shares, Issued	62,784,250	34,586,250
Common Class D [Member]
Common Stock, Shares Authorized	500,000,000	500,000,000
Common Stock, Shares, Issued	42,738,750	42,738,750

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Cash Flows from Operating Activities
Net income	$ 111	$ 53	[1],[2],[3]
Adjustments to reconcile net income to net cash provided by operating activities:
Income (Loss) from Equity Method Investments	(29)	(19)	[1],[2]
Distributions from unconsolidated affiliates	39	40	[4]
Depreciation, amortization and ARO accretion	226	224	[4]
Amortization of financing costs and debt discounts	15	13	[4]
Amortization of intangibles and out-of-market contracts	57	41	[4]
Adjustment for debt extinguishment	0	(9)	[1],[2],[4]
Changes in income taxes	25	8	[4]
Changes in derivative instruments	(5)	(38)	[4]
Disposal of asset components	5	2
Changes in prepaid and accrued capacity payments	2	(1)
Changes in other working capital	(7)	(22)	[4]
Net Cash Provided by Operating Activities	439	310	[4]
Cash Flows from Investing Activities
Acquisition of businesses, net of cash acquired	0	37	[4]
Acquisition of Drop Down Assets, net of cash acquired	77	489	[4]
Capital expenditures	(16)	(17)	[4]
Increase in restricted cash	(7)	(24)	[4]
Decrease in notes receivable	11	13	[4]
Proceeds from renewable energy grants	0	22	[4]
Return of investment from unconsolidated affiliates	16	16
Investments in unconsolidated affiliates	(69)	(351)	[4]
Net Cash Used in Investing Activities	(142)	(867)	[4]
Cash Flows from Financing Activities
Net contributions from noncontrolling interests	7	123	[4]
Distributions to NRG for CVSR and NRG Wind TE Holdco	(122)	(52)	[4]
Proceeds from the issuance of common stock	0	599	[4]
Payment of dividends and distributions to shareholders	(127)	(99)	[4]
Payment of debt issuance costs	6	13	[4]
Net (payments for) borrowings from the revolving credit facility	(306)	92
Proceeds from the issuance of long-term debt	550	292
Payments for long-term debt	(204)	(669)	[4]
Net Cash (Used in) Provided by Financing Activities	(208)	273	[4]
Net Increase (Decrease) in Cash and Cash Equivalents	89	(284)	[4]
Cash and Cash Equivalents at Beginning of Period	111	429	[4]
Cash and Cash Equivalents at End of Period	$ 200	$ 145	[4]
[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[3]	a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[4]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Nature of Business

Nature of Business	9 Months Ended
	Sep. 30, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Nature of Business	Nature of Business NRG Yield, Inc., together with its consolidated subsidiaries, or the Company, is a dividend growth-oriented company formed by NRG as a Delaware corporation on December 20, 2012, to serve as the primary vehicle through which NRG owns, operates and acquires contracted renewable and conventional generation and thermal infrastructure assets. NRG Yield, Inc. owns 100% of the Class A units and Class C units of NRG Yield LLC, including a controlling interest through its position as managing member. NRG Yield LLC, through its wholly owned subsidiary, NRG Yield Operating LLC, is the holder of a portfolio of renewable and conventional generation and thermal infrastructure assets, primarily located in the Northeast, Southwest and California regions of the U.S. NRG Yield, Inc. consolidates the results of NRG Yield LLC through its controlling interest, with NRG's interest shown as noncontrolling interest in the financial statements. On May 14, 2015, NRG Yield, Inc. completed a stock split whereby each outstanding share of Class A common stock was split into one share of Class A common stock and one share of Class C common stock, and each outstanding share of Class B common stock was split into one share of Class B common stock and one share of Class D common stock. The stock split is referred to as the Recapitalization and all references to share or per share amounts in the accompanying consolidated financial statements and applicable disclosures have been retrospectively adjusted to reflect the Recapitalization. In addition, on June 29, 2015, NRG Yield, Inc. completed the issuance of 28,198,000 shares of Class C common stock for net proceeds of $599 million . The holders of NRG Yield, Inc.'s outstanding shares of Class A and Class C common stock are entitled to dividends as declared. NRG receives its distributions from NRG Yield LLC through its ownership of NRG Yield LLC Class B and Class D units. The following table represents the structure of the Company as of September 30, 2016 : As of September 30, 2016 , the Company's operating assets are comprised of the following projects: Projects Percentage Ownership Net Capacity (MW) (a) Offtake Counterparty Expiration Conventional El Segundo 100 % 550 Southern California Edison 2023 GenConn Devon 50 % 95 Connecticut Light & Power 2040 GenConn Middletown 50 % 95 Connecticut Light & Power 2041 Marsh Landing 100 % 720 Pacific Gas and Electric 2023 Walnut Creek 100 % 485 Southern California Edison 2023 1,945 Utility Scale Solar Alpine 100 % 66 Pacific Gas and Electric 2033 Avenal 50 % 23 Pacific Gas and Electric 2031 Avra Valley 100 % 26 Tucson Electric Power 2032 Blythe 100 % 21 Southern California Edison 2029 Borrego 100 % 26 San Diego Gas and Electric 2038 CVSR 100 % 250 Pacific Gas and Electric 2038 Desert Sunlight 250 25 % 63 Southern California Edison 2035 Desert Sunlight 300 25 % 75 Pacific Gas and Electric 2040 Kansas South 100 % 20 Pacific Gas and Electric 2033 Roadrunner 100 % 20 El Paso Electric 2031 TA High Desert 100 % 20 Southern California Edison 2033 610 Distributed Solar AZ DG Solar Projects 100 % 5 Various 2025 - 2033 PFMG DG Solar Projects 51 % 4 Various 2032 9 Wind Alta I 100 % 150 Southern California Edison 2035 Alta II 100 % 150 Southern California Edison 2035 Alta III 100 % 150 Southern California Edison 2035 Alta IV 100 % 102 Southern California Edison 2035 Alta V 100 % 168 Southern California Edison 2035 Alta X (b) 100 % 137 Southern California Edison 2038 Alta XI (b) 100 % 90 Southern California Edison 2038 Buffalo Bear 100 % 19 Western Farmers Electric Co-operative 2033 Crosswinds 74.3 % 16 Corn Belt Power Cooperative 2027 Elbow Creek 75 % 92 NRG Power Marketing LLC 2022 Elkhorn Ridge 50.3 % 41 Nebraska Public Power District 2029 Forward 75 % 22 Constellation NewEnergy, Inc. 2017 Goat Wind 74.9 % 113 Dow Pipeline Company 2025 Hardin 74.3 % 11 Interstate Power and Light Company 2027 Laredo Ridge 100 % 80 Nebraska Public Power District 2031 Lookout 75 % 29 Southern Maryland Electric Cooperative 2030 Odin 74.9 % 15 Missouri River Energy Services 2028 Pinnacle 100 % 55 Maryland Department of General Services and University System of Maryland 2031 San Juan Mesa 56.3 % 68 Southwestern Public Service Company 2025 Sleeping Bear 75 % 71 Public Service Company of Oklahoma 2032 South Trent 100 % 101 AEP Energy Partners 2029 Spanish Fork 75 % 14 PacifiCorp 2028 Spring Canyon II (b) 90.1 % 29 Platte River Power Authority 2039 Spring Canyon III (b) 90.1 % 25 Platte River Power Authority 2039 Taloga 100 % 130 Oklahoma Gas & Electric 2031 Wildorado 74.9 % 121 Southwestern Public Service Company 2027 1,999 Projects Percentage Ownership Net Capacity (MW) (a) Offtake Counterparty Expiration Thermal Thermal equivalent MWt (c) 100 % 1,315 Various Various NRG Dover Energy Center LLC 100 % 103 NRG Power Marketing LLC 2018 Thermal generation 100 % 20 Various Various 1,438 Total net capacity (excluding equivalent MWt) (d) 4,686 (a) Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2016 . (b) Projects are part of tax equity arrangements. (c) For thermal energy, net capacity represents MWt for steam or chilled water and excludes 134 MWt available under the right-to-use provisions contained in agreements between two of the Company's thermal facilities and certain of its customers. (d) Total net capacity excludes 43 MW for RPV Holdco and 52 MW for DGPV Holdco 1 and DGPV Holdco 2 projects, of which the Company's net interests are 41 MW and 49 , respectively, based on cash to be distributed. These projects are part of tax equity arrangements and are consolidated by NRG, as further described in Note 4 , Variable Interest Entities, or VIEs . Substantially all of the Company's generation assets are under long-term contractual arrangements for the output or capacity from these assets. The thermal assets are comprised of district energy systems and combined heat and power plants that produce steam, hot water and/or chilled water and in some instances, electricity, at a central plant. Three out of the fourteen district energy systems are subject to rate regulation by state public utility commissions while the other district energy systems have rates determined by negotiated bilateral contracts. As described in Note 11 , Related Party Transactions , the Company has a management services agreement with NRG for various services, including human resources, accounting, tax, legal, information systems, treasury, and risk management. Stockholders' equity represents the equity associated with the Class A and Class C common stockholders, the equity associated with the Class B and Class D common stockholder, NRG, and the third-party interests under certain tax equity arrangements classified as noncontrolling interest. As described in Note 3 , Business Acquisitions , on September 1, 2016, the Company acquired the remaining 51.05% of CVSR, or the CVSR Drop Down, from NRG for cash consideration of $78.5 million plus an immaterial working capital adjustment. Prior to the transaction, the Company recorded its 48.95% interest in CVSR as an equity method investment. The acquisition of the CVSR Drop Down was accounted for as a transfer of entities under common control. The accounting guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect from the beginning of the financial statement period or from the date the entities were under common control (if later than the beginning of the financial statement period). Accordingly, in connection with the retrospective adjustment of prior periods, the Company removed the equity method investment from all prior periods and adjusted its financial statements to reflect its results of operations, financial position and cash flows as if it had consolidated CVSR from the beginning of the financial statement period. Previously, on November 3, 2015, the Company acquired 75% of the Class B interests of NRG Wind TE Holdco, or the November 2015 Drop Down Assets, from NRG for cash consideration of $209 million . In February 2016, NRG made a final working capital payment of $2 million , reducing total cash consideration to $207 million . The Company has recorded all minority interests in NRG Wind TE Holdco as noncontrolling interest in the consolidated financial statements for all periods presented. On January 2, 2015, the Company acquired the Laredo Ridge, Tapestry, and Walnut Creek projects, or the January 2015 Drop Down Assets, for total cash consideration of $489 million , including $9 million for working capital. The recast for the above transactions, referred to as Drop Down Assets, did not affect net income attributable to NRG Yield, Inc., weighted average number of shares outstanding, earnings per share or dividends. The accompanying unaudited interim consolidated financial statements have been prepared in accordance with the SEC’s regulations for interim financial information and with the instructions to Form 10-Q. Accordingly, they do not include all of the information and notes required by GAAP for complete financial statements. The following notes should be read in conjunction with the accounting policies and other disclosures as set forth in the notes to the consolidated financial statements for the year ended December 31, 2015 included in the Company's September 6, 2016 Form 8-K. Interim results are not necessarily indicative of results for a full year. In the opinion of management, the accompanying unaudited interim consolidated financial statements contain all material adjustments consisting of normal and recurring accruals necessary to present fairly the Company's consolidated financial position as of September 30, 2016 , and the results of operations, comprehensive income (loss) and cash flows for the three and nine months ended September 30, 2016 and 2015 .

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Use of Estimates The preparation of consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions. These estimates and assumptions impact the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities as of the date of the consolidated financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could be different from these estimates. Accumulated Depreciation, Accumulated Amortization The following table presents the accumulated depreciation included in the property, plant and equipment, net, and accumulated amortization included in intangible assets, net, respectively, as of September 30, 2016 and December 31, 2015: September 30, 2016 December 31, 2015 (In millions) Property, Plant and Equipment Accumulated Depreciation $ 1,002 $ 782 Intangible Assets Accumulated Amortization 151 93 Noncontrolling Interests The following table reflects the changes in the Company's noncontrolling interest balance: (In millions) Balance as of December 31, 2015 $ 897 Capital contributions from tax equity investors, net of distributions 7 November 2015 Drop Down Assets working capital payment 2 Payment for CVSR Drop Down (79 ) Pre-acquisition net income of Drop Down Assets 10 Comprehensive income 16 Distributions to NRG for Drop Down Assets (172 ) Yield LLC distributions to NRG (59 ) Balance as of September 30, 2016 $ 622 Distributions to NRG for Drop Down Assets Distributions to NRG for Drop Down Assets relate to NRG's 25% interest in the November 2015 Drop Down Assets as well as NRG's 51.05% interest in CVSR prior to its acquisition by the Company. This amount includes cash and non-cash distributions and includes portion of the proceeds from the senior notes issued under the CVSR Holdco Financing Arrangement on July 15, 2016, as described in Note 7, Long-term Debt . Yield LLC Distributions to NRG The following table lists the distributions paid on NRG Yield LLC's Class B and D units during the nine months ended September 30, 2016 : Third Quarter 2016 Second Quarter 2016 First Quarter 2016 Distributions per Class B Unit 0.24 $ 0.23 $ 0.225 Distributions per Class D Unit 0.24 $ 0.23 $ 0.225 On November 2, 2016 , NRG Yield LLC declared a distribution on its units of $0.25 per unit payable on December 15, 2016 to unit holders of record as of December 1, 2016 . Reclassifications Certain prior-year amounts have been reclassified for comparative purposes. Recent Accounting Developments ASU 2016-16 - In October 2016, the FASB issued ASU No. 2016-16, Income Taxes (Topic 740) , Intra-Entity Transfers of Assets Other Than Inventory, or ASU No. 2016-16. The amendments of ASU No. 2016-16 were issued to improve the accounting for the income tax consequences of intra-entity transfers of assets other than inventory. Current GAAP prohibits the recognition of current and deferred income taxes for an intra-entity asset transfer until the asset has been sold to an outside party which has resulted in diversity in practice and increased complexity within financial reporting. The amendments of ASU No. 2016-16 would require an entity to recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs and do not require new disclosure requirements. The amendments of ASU No. 2016-16 are effective for annual reporting periods beginning after December 15, 2017, and interim periods within those annual periods. Early adoption is permitted and the adoption of ASU No. 2016-16 should be applied on a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption. The Company is currently evaluating the impact of the standard on the Company’s results of operations, cash flows and financial position. ASU 2016-15 — In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows (Topic 230) , Classification of Certain Cash Receipts and Cash Payments, or ASU No. 2016-15. The amendments of ASU No. 2016-15 were issued to address eight specific cash flow issues for which stakeholders have indicated to the FASB that a diversity in practice existed in how entities were presenting and classifying these items in the statement of cash flows. The issues addressed by ASU No. 2016-15 include but are not limited to the classification of debt prepayment and debt extinguishment costs, payments made for contingent consideration for a business combination, proceeds from the settlement of insurance proceeds, distributions received from equity method investees and separately identifiable cash flows and the application of the predominance principle. The amendments of ASU No. 2016-15 are effective for public entities for fiscal years beginning after December 15, 2017 and interim periods in those fiscal years. Early adoption is permitted, including adoption in an interim fiscal period with all amendments adopted in the same period. The adoption of ASU No. 2016-15 is required to be applied retrospectively. The Company is currently evaluating the impact of the standard on the Company's statement of cash flows. ASU 2016-07 — In March 2016, the FASB issued ASU No. 2016-07, Investments - Equity Method and Joint Ventures (Topic 323), or ASU No. 2016-07. The amendments of ASU No. 2016-07 eliminate the requirement that when an investment qualifies for use of the equity method as a result of an increase in the level of ownership interest or degree of influence, an investor must adjust the investment, results of operations, and retained earnings retroactively on a step-by-step basis as if the equity method had been in effect during all previous periods that the investment had been held. The amendments require that the equity method investor add the cost of acquiring the additional interest in the investee to the current basis of the investor's previously held interest and adopt the equity method of accounting with no retroactive adjustment to the investment. In addition, ASU No. 2016-07 requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in accumulated other comprehensive income at the date the investment becomes qualified for use of the equity method. The guidance in ASU No. 2016-07 is effective for fiscal years beginning after December 15, 2016, and interim periods within those annual periods. The adoption of ASU No. 2016-07 is required to be applied prospectively and early adoption is permitted. The Company does not expect the standard to have a material impact on its results of operations, cash flows and financial position. ASU 2016-02 — In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), or ASU No. 2016-02. The amendments of ASU No. 2016-02 complete the joint effort between the FASB and the International Accounting Standards Board, or IASB, to develop a common leasing standard for GAAP and International Financial Reporting Standards, or IFRS, with the objective to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and to improve financial reporting. The guidance in ASU No. 2016-02 provides that a lessee that may have previously accounted for a lease as an operating lease under current GAAP should recognize the assets and liabilities that arise from a lease on the balance sheet. In addition, ASU No. 2016-02 expands the required quantitative and qualitative disclosures with regards to lease arrangements. The guidance in ASU No. 2016-02 is effective for fiscal years beginning after December 15, 2018, and interim periods within those annual periods. The adoption of ASU No. 2016-02 is required to be applied using a modified retrospective approach for the earliest period presented and early adoption is permitted. The Company is currently working through an adoption plan which includes the evaluation of lease contracts compared to the new standard and evaluating the impact of ASU No.2016-02 on the Company's results of operations, cash flows and financial position. ASU 2016-01 — In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities , or ASU No. 2016-01. The amendments of ASU No. 2016-01 eliminate available-for-sale classification of equity investments and require that equity investments (except those accounted for under the equity method of accounting, or those that result in consolidation of the investee) to be generally measured at fair value with changes in fair value recognized in net income. Further, the amendments require financial assets and financial liabilities to be presented separately in the notes to the financial statements, grouped by measurement category and form of financial asset. The guidance in ASU No. 2016-01 is effective for financial statements issued for fiscal years beginning after December 15, 2017, and interim periods within those annual periods. The Company is currently evaluating the impact of the standard on the Company's results of operations, cash flows and financial position. ASU 2015-16 — In September 2015, the FASB issued ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments , or ASU No. 2015-16. The amendments of ASU No. 2015-16 require that an acquirer recognize measurement period adjustments to the provisional amounts recognized in a business combination in the reporting period during which the adjustments are determined. Additionally, the amendments of ASU No. 2015-16 require the acquirer to record in the same period's financial statements the effect on earnings of changes in depreciation, amortization or other income effects, if any, as a result of the measurement period adjustment, calculated as if the accounting had been completed at the acquisition date as well as disclosing on either the face of the income statement or in the notes the portion of the amount recorded in current period earnings that would have been recorded in previous reporting periods. The guidance in ASU No. 2015-16 is effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. The amendments should be applied prospectively. The Company adopted this standard on January 1, 2016, and the adoption of this standard did not impact the Company's results of operations, cash flows or financial position. ASU 2014-09 — In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), or ASU No. 2014-09. The amendments of ASU No. 2014-09 complete the joint effort between the FASB and the IASB, to develop a common revenue standard for GAAP and IFRS, and to improve financial reporting. In addition to ASU No. 2014-09, the FASB has issued additional guidance which provides further clarification on Topic 606 including ASU No. 2016-08, ASU No. 2016-10, ASU No. 2016-12. The guidance under Topic 606 provides that an entity should recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled to in exchange for the goods or services provided and establishes a four step process to be applied by an entity in evaluating its contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which formally deferred the effective date by one year to make the guidance of ASU No. 2014-09 effective for annual reporting periods beginning after December 15, 2017, including interim periods therein. Early adoption is permitted, but not prior to the original effective date, which was for annual reporting periods beginning after December 15, 2016. The Company is working through an adoption plan which includes the evaluation of revenue contracts compared to the new standard and evaluating the impact of Topic 606 on the Company' results of operations, cash flows and financial position.

Business Acquisitions

Business Acquisitions	9 Months Ended
	Sep. 30, 2016
Business Combinations [Abstract]
Business Acquisition	Business Acquisitions 2016 Acquisitions CVSR Drop Down — Prior to September 1, 2016, the Company had a 48.95% interest in CVSR, which was accounted for as an equity method investment. On September 1, 2016, the Company acquired from NRG the remaining 51.05% interest of CVSR Holdco LLC, which indirectly owns the CVSR solar facility, for total cash consideration of $78.5 million plus an immaterial working capital adjustment. The Company also assumed additional debt of $496 million , which represents 51.05% of the CVSR project level debt and 51.05% of the notes issued under the CVSR Holdco Financing Agreement, as further described in Note 7, Long-term Debt , as of the closing date. The acquisition was funded with cash on hand. The assets and liabilities transferred to the Company relate to interests under common control by NRG and were recorded at historical cost in accordance with ASC 805-50, Business Combinations - Related Issues . The difference between the cash paid and historical value of the entities' equity was recorded as a distribution to NRG with the offset to noncontrolling interest. Because the transaction constituted a transfer of net assets under common control, the guidance requires retrospective combination of the entities for all periods presented as if the combination has been in effect since the inception of common control. In connection with the retrospective adjustment of prior periods, the Company has removed the equity method investment from all prior periods and adjusted its financial statements to reflect its results of operations, financial position and cash flows as if it had consolidated CVSR from the beginning of the financial statement period. As of June 30, 2016, the Company's recast consolidated balance sheet included a net receivable of $ 67 million related to current litigation with SunPower pursuant to indemnities in the project. The agreement between NRG and the Company for the CVSR Drop Down acquisition specified that all amounts related to the litigation with SunPower were excluded from the acquisition. Accordingly, prior to close of the transaction, the net receivable was transferred to NRG as a net reduction to its ownership interest in CVSR. The following is the summary of historical net liabilities assumed in connection with the CVSR Drop Down as of September 1, 2016: CVSR (In millions) Current assets $ 95 Property, plant and equipment 826 Non-current assets 13 Total assets 934 Debt (a) 966 Other current and non-current liabilities 12 Total liabilities 978 Net liabilities assumed (44 ) Accumulated Other Comprehensive Loss (25 ) Historical Net Liabilities Assumed $ (19 ) (a) Net of deferred financing costs of $5 million . Since the acquisition date, CVSR has contributed $9 million in operating revenues and $4 million in net income to the Company. 2015 Acquisitions November 2015 Drop Down Assets from NRG — On November 3, 2015, the Company acquired the November 2015 Drop Down Assets, a portfolio of 12 wind facilities totaling 814 net MW, from NRG for cash consideration of $209 million , subject to working capital adjustments. In February 2016, NRG made a final working capital payment of $2 million , reducing total cash consideration to $207 million . The Company is responsible for its pro-rata share of non-recourse project debt of $193 million and noncontrolling interest associated with a tax equity structure of $159 million (as of the acquisition date). The Company funded the acquisition with borrowings from its revolving credit facility. The assets and liabilities transferred to the Company relate to interests under common control by NRG and were recorded at historical cost. The difference between the cash paid and historical value of the entities' equity was recorded as a distribution from NRG with the offset to noncontrolling interest. The Class A interests of NRG Wind TE Holdco are owned by a tax equity investor, or TE Investor, who receives 99% of allocations of taxable income and other items until the flip point, which occurs when the TE Investor obtains a specified return on its initial investment, at which time the allocations to the TE Investor change to 8.53% . The Company generally receives 75% of CAFD until the flip point, at which time the allocations to the Company of CAFD change to 68.60% . If the flip point has not occurred by a specified date, 100% of CAFD is allocated to the TE Investor until the flip point occurs. NRG Wind TE Holdco is a VIE and the Company is the primary beneficiary, through its position as managing member, and consolidates NRG Wind TE Holdco. Desert Sunlight — On June 29, 2015, the Company acquired 25% of the membership interest in Desert Sunlight Investment Holdings, LLC, which owns two solar photovoltaic facilities that total 550 MW, located in Desert Center, California from EFS Desert Sun, LLC, an affiliate of GE Energy Financial Services for a purchase price of $285 million . Power generated by the facilities is sold to Southern California Edison and Pacific Gas and Electric under long-term PPAs with approximately 20 years and 25 years of remaining contract life, respectively. The Company accounts for its 25% investment as an equity method investment. Spring Canyon — On May 7, 2015, the Company acquired a 90.1% interest in Spring Canyon II, a 32 MW wind facility, and Spring Canyon III, a 28 MW wind facility, each located in Logan County, Colorado, from Invenergy Wind Global LLC. The purchase price was funded with cash on hand. Power generated by Spring Canyon II and Spring Canyon III is sold to Platte River Power Authority under long-term PPAs with approximately 24 years of remaining contract life. University of Bridgeport Fuel Cell — On April 30, 2015, the Company completed the acquisition of the University of Bridgeport Fuel Cell project in Bridgeport, Connecticut from FuelCell Energy, Inc. The project added an additional 1.4 MW of thermal capacity to the Company's portfolio, with a 12 -year contract, with the option for a 7 -year extension. The acquisition is reflected in the Company's Thermal segment. January 2015 Drop Down Assets from NRG — On January 2, 2015, the Company acquired the following projects from NRG: (i) Laredo Ridge, an 80 MW wind facility located in Petersburg, Nebraska, (ii) Tapestry, which includes Buffalo Bear, a 19 MW wind facility in Buffalo, Oklahoma; Taloga, a 130 MW wind facility in Putnam, Oklahoma; and Pinnacle, a 55 MW wind facility in Keyser, West Virginia, and (iii) Walnut Creek, a 485 MW natural gas facility located in City of Industry, California, for total cash consideration of $489 million , including $9 million for working capital, plus assumed project-level debt of $737 million . The Company funded the acquisition with cash on hand and drawings under its revolving credit facility. The assets and liabilities transferred to the Company relate to interests under common control by NRG and were recorded at historical cost. The difference between the cash paid and the historical value of the entities' equity of $61 million , as well as $23 million of AOCL, was recorded as a distribution to NRG and reduced the balance of its noncontrolling interest.

Variable Interest Entities

Variable Interest Entities	9 Months Ended
	Sep. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Investments Accounted for by the Equity Method and Variable Interest Entities	Variable Interest Entities, or VIEs Entities that are Consolidated The Company has a controlling financial interest in certain entities which have been identified as VIEs under ASC 810, Consolidations, or ASC 810. These arrangements are primarily related to tax equity arrangements entered into with third parties in order to monetize certain tax credits associated with wind facilities, as further described in Note 5 , Investments Accounted for by the Equity Method and Variable Interest Entities , to the Company's consolidated financial statements included in the Company's September 6, 2016 Form 8-K. Summarized financial information for the Company's consolidated VIEs consisted of the following as of September 30, 2016 : (In millions) NRG Wind TE Holdco Alta Wind TE Holdco Spring Canyon Other current and non-current assets $ 189 $ 19 $ 4 Property, plant and equipment 635 466 101 Intangible assets 2 278 — Total assets 826 763 105 Current and non-current liabilities 225 9 6 Total liabilities 225 9 6 Noncontrolling interest 209 118 69 Net assets less noncontrolling interests $ 392 $ 636 $ 30 Entities that are not Consolidated The Company has interests in entities that are considered VIEs under ASC 810, but for which it is not considered the primary beneficiary. The Company accounts for its interests in these entities under the equity method of accounting, as further described in Note 5 , Investments Accounted for by the Equity Method and Variable Interest Entities , to the Company's consolidated financial statements included in the Company's September 6, 2016 Form 8-K. NRG DGPV Holdco 1 LLC — The Company and NRG maintain a partnership, NRG DGPV Holdco 1 LLC, or DGPV Holdco 1, the purpose of which is to own or purchase solar power generation projects and other ancillary related assets from NRG Renew LLC or its subsidiaries via intermediate funds, including: (i) a tax equity-financed portfolio of 10 recently completed community solar projects representing approximately 8 MW with a weighted average remaining PPA term of 20 years ; and (ii) a tax equity-financed portfolio of approximately 12 commercial photovoltaic systems representing approximately 37 MW with a weighted average remaining PPA term of 19 years . Both of these investments relate to the Company's $100 million commitment to distributed solar projects in partnership with NRG. NRG DGPV Holdco 2 LLC — On February 29, 2016, the Company and NRG entered into an additional partnership by forming NRG DGPV Holdco 2 LLC, or DGPV Holdco 2, to own or purchase solar power generation projects representing approximately 7 MW with a weighted average remaining PPA term of 18 years as well as other ancillary related assets from NRG Renew LLC or its subsidiaries, via intermediate funds. Under this partnership, the Company committed to fund up to $50 million of capital. The Company's maximum exposure to loss is limited to its equity investment in DGPV Holdco 1 and DGPV Holdco 2, which was $77 million on a combined basis as of September 30, 2016 . NRG RPV Holdco 1 LLC — The Company and NRG Residential Solar Solutions LLC, a subsidiary of NRG, maintain a partnership, NRG RPV Holdco 1 LLC, or RPV Holdco, that holds operating portfolios of residential solar assets developed by NRG's residential solar business, including: (i) an existing, unlevered portfolio of over 2,000 leases across nine states representing approximately 15 MW with a weighted average remaining lease term of approximately 17 years that was acquired outside of the partnership; and (ii) a tax equity-financed portfolio of approximately 5,400 leases representing approximately 28 MW, with an average lease term for the existing and new leases of approximately 17 to 20 years . In addition to the acquisition of the unlevered portfolio of leases, the Company had previously committed to fund up to $150 million of capital to invest in the tax equity financed portfolio, which was reduced to $100 million in February 2016. On August 5, 2016, the Company and NRG amended the RPV Holdco partnership to further reduce that capital commitment of $100 million to $60 million in connection with NRG’s change in business model approach in the residential solar business. As of September 30, 2016, the Company had contributed $57 million of this amount. The Company's maximum exposure to loss is limited to its equity investment, which was $70 million as of September 30, 2016 . GenConn Energy LLC — The Company has a 50% interest in GCE Holding LLC, the owner of GenConn, which owns and operates two 190 MW peaking generation facilities in Connecticut at the Devon and Middletown sites. As of September 30, 2016 , the Company's investment in GenConn was $106 million and its maximum exposure to loss is limited to its equity investment. The following table presents summarized financial information for GCE Holding LLC: Three months ended September 30, Nine months ended September 30, (In millions) 2016 2015 2016 2015 Income Statement Data: Operating revenues $ 18 $ 21 $ 54 $ 61 Operating income 9 9 28 29 Net income $ 7 $ 6 $ 20 $ 20 September 30, 2016 December 31, 2015 Balance Sheet Data: (In millions) Current assets $ 29 $ 36 Non-current assets 403 416 Current liabilities 12 16 Non-current liabilities $ 208 $ 215

Fair Value of Financial Instrum

Fair Value of Financial Instruments	9 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	Fair Value of Financial Instruments Fair Value Accounting under ASC 820 ASC 820 establishes a fair value hierarchy that prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows: • Level 1—quoted prices (unadjusted) in active markets for identical assets or liabilities that the Company has the ability to access as of the measurement date. • Level 2—inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data. • Level 3—unobservable inputs for the asset or liability only used when there is little, if any, market activity for the asset or liability at the measurement date. In accordance with ASC 820, the Company determines the level in the fair value hierarchy within which each fair value measurement in its entirety falls, based on the lowest level input that is significant to the fair value measurement. For cash and cash equivalents, restricted cash, accounts receivable, accounts receivable — affiliate, accounts payable, accounts payable — affiliate, accrued expenses and other liabilities, the carrying amounts approximate fair value because of the short-term maturity of those instruments and are classified as Level 1 within the fair value hierarchy. The estimated carrying amounts and fair values of the Company’s recorded financial instruments not carried at fair market value are as follows: As of September 30, 2016 As of December 31, 2015 Carrying Amount Fair Value Carrying Amount Fair Value (In millions) Assets: Notes receivable, including current portion $ 35 $ 35 $ 47 $ 47 Liabilities: Long-term debt, including current portion $ 5,704 $ 5,729 $ 5,656 $ 5,538 The fair value of the Company's publicly-traded long-term debt is based on quoted market prices and is classified as Level 2 within the fair value hierarchy. The fair value of debt securities, non-publicly traded long-term debt and certain notes receivable of the Company are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments with equivalent credit quality and are classified as Level 3 within the fair value hierarchy. The following table presents the level within the fair value hierarchy for long-term debt, including current portion as of September 30, 2016 and December 31, 2015: As of September 30, 2016 As of December 31, 2015 Level 2 Level 3 Level 2 Level 3 (In millions) Long-term debt, including current portion $ 1,478 $ 4,251 $ 978 $ 4,560 Recurring Fair Value Measurements The Company records its derivative assets and liabilities at fair value on its consolidated balance sheet. There were no derivative asset positions on the Company's consolidated balance sheet as of December 31, 2015 . The following table presents assets and liabilities measured and recorded at fair value on the Company's consolidated balance sheets on a recurring basis and their level within the fair value hierarchy: As of September 30, 2016 As of December 31, 2015 Fair Value (a) Fair Value (a) (In millions) Level 2 Level 2 Derivative assets: Commodity contracts $ 1 $ — Total assets 1 — Derivative liabilities: Commodity contracts 1 2 Interest rate contracts 138 98 Total liabilities $ 139 $ 100 (a) There were no derivative assets or liabilities classified as Level 1 or Level 3 as of September 30, 2016 , and December 31, 2015 . Derivative Fair Value Measurements The Company's contracts are non-exchange-traded and valued using prices provided by external sources. For the Company’s energy markets, management receives quotes from multiple sources. To the extent that multiple quotes are received, the prices reflect the average of the bid-ask mid-point prices obtained from all sources believed to provide the most liquid market for the commodity. The fair value of each contract is discounted using a risk free interest rate. In addition, a credit reserve is applied to reflect credit risk, which is, for interest rate swaps, calculated based on credit default swaps using the bilateral method. For commodities, to the extent that the net exposure under a specific master agreement is an asset, the Company uses the counterparty’s default swap rate. If the net exposure under a specific master agreement is a liability, the Company uses NRG's default swap rate. For interest rate swaps and commodities, the credit reserve is added to the discounted fair value to reflect the exit price that a market participant would be willing to receive to assume the liabilities or that a market participant would be willing to pay for the assets. As of September 30, 2016 , the credit reserve resulted in a $4 million increase in fair value, which was composed of a $3 million gain in OCI and $1 million reduction in interest expense. It is possible that future market prices could vary from those used in recording assets and liabilities and such variations could be material. Concentration of Credit Risk In addition to the credit risk discussion in Note 2 , Summary of Significant Accounting Policies , to the Company's consolidated financial statements included in the Company's September 6, 2016 Form 8-K, the following is a discussion of the concentration of credit risk for the Company's financial instruments. Credit risk relates to the risk of loss resulting from non-performance or non-payment by counterparties pursuant to the terms of their contractual obligations. The Company monitors and manages credit risk through credit policies that include: (i) an established credit approval process; (ii) daily monitoring of counterparties' credit limits; (iii) the use of credit mitigation measures such as margin, collateral, prepayment arrangements, or volumetric limits; (iv) the use of payment netting agreements; and (v) the use of master netting agreements that allow for the netting of positive and negative exposures of various contracts associated with a single counterparty. Risks surrounding counterparty performance and credit could ultimately impact the amount and timing of expected cash flows. The Company seeks to mitigate counterparty risk by having a diversified portfolio of counterparties. Counterparty credit exposure includes credit risk exposure under certain long-term agreements, including solar and other PPAs. As external sources or observable market quotes are not available to estimate such exposure, the Company estimates the exposure related to these contracts based on various techniques including, but not limited to, internal models based on a fundamental analysis of the market and extrapolation of observable market data with similar characteristics. Based on these valuation techniques, as of September 30, 2016 , credit risk exposure to these counterparties attributable to the Company's ownership interests was approximately $2.6 billion for the next five years . The majority of these power contracts are with utilities with strong credit quality and public utility commission or other regulatory support, as further described in Note 12 , Segment Reporting , to the Company's consolidated financial statements included in the Company's September 6, 2016 Form 8-K . However, such regulated utility counterparties can be impacted by changes in government regulations, which the Company is unable to predict.

Accounting for Derivative Instr

Accounting for Derivative Instruments and Hedging Activities	9 Months Ended
	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Accounting for Derivative Instruments and Hedging Activities	Accounting for Derivative Instruments and Hedging Activities This footnote should be read in conjunction with the complete description under Note 7, Accounting for Derivative Instruments and Hedging Activities , to the Company's consolidated financial statements included in the Company's September 6, 2016 Form 8-K. Energy-Related Commodities As of September 30, 2016 , the Company had forward contracts for the purchase of fuel commodities relating to the forecasted usage of the Company’s district energy centers extending through 2018. At September 30, 2016 , these contracts were not designated as cash flow or fair value hedges. Interest Rate Swaps As of September 30, 2016 , the Company had interest rate derivative instruments on non-recourse debt extending through 2031, most of which are designated as cash flow hedges. Volumetric Underlying Derivative Transactions The following table summarizes the net notional volume buy/(sell) of the Company's open derivative transactions broken out by commodity: Total Volume September 30, 2016 December 31, 2015 Commodity Units (In millions) Natural Gas MMBtu 3 4 Interest Dollars $ 1,875 $ 1,991 Fair Value of Derivative Instruments There were no derivative asset positions on the balance sheet as of December 31, 2015 . The following table summarizes the fair value within the derivative instrument valuation on the balance sheet: Fair Value Derivative Assets Derivative Liabilities September 30, 2016 September 30, 2016 December 31, 2015 (In millions) Derivatives Designated as Cash Flow Hedges: Interest rate contracts current $ — $ 29 $ 34 Interest rate contracts long-term — 94 56 Total Derivatives Designated as Cash Flow Hedges — 123 90 Derivatives Not Designated as Cash Flow Hedges: Interest rate contracts current — 2 3 Interest rate contracts long-term — 13 5 Commodity contracts current 1 1 2 Total Derivatives Not Designated as Cash Flow Hedges 1 16 10 Total Derivatives $ 1 $ 139 $ 100 The Company has elected to present derivative assets and liabilities on the balance sheet on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. As of September 30, 2016 and December 31, 2015 , there were no offsetting amounts at the counterparty master agreement level or outstanding collateral paid or received. Accumulated Other Comprehensive Loss The following table summarizes the effects on the Company’s accumulated OCL balance attributable to interest rate swaps designated as cash flow hedge derivatives, net of tax: Three months ended September 30, Nine months ended September 30, 2016 2015 (a) 2016 2015 (a) (In millions) Accumulated OCL beginning balance $ (140 ) $ (73 ) $ (83 ) $ (76 ) Reclassified from accumulated OCL to income due to realization of previously deferred amounts 4 5 10 12 Mark-to-market of cash flow hedge accounting contracts 17 (36 ) (46 ) (40 ) Accumulated OCL ending balance, net of income tax benefit of $29 and $19, respectively (119 ) (104 ) (119 ) (104 ) Accumulated OCL attributable to noncontrolling interests (71 ) (72 ) (71 ) (72 ) Accumulated OCL attributable to NRG Yield, Inc. $ (48 ) $ (32 ) $ (48 ) $ (32 ) Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $4 $ 16 $ 16 (a) Retrospectively adjusted as discussed in Note 1, Nature of Business . Amounts reclassified from accumulated OCL into income and amounts recognized in income from the ineffective portion of cash flow hedges are recorded to interest expense. There was no ineffectiveness for the three and nine months ended September 30, 2016 and 2015 . Impact of Derivative Instruments on the Statements of Income The Company has interest rate derivative instruments that are not designated as cash flow hedges. The effect of interest rate hedges is recorded to interest expense. For the three months ended September 30, 2016 , and 2015 , the impact to the consolidated statements of income was a gain of $2 million and a loss of $6 million , respectively. For the nine months ended September 30, 2016 , and 2015 , the impact to the consolidated statements of income was a loss of $7 million and a gain of $13 million , respectively. A portion of the Company’s derivative commodity contracts relates to its Thermal Business for the purchase of fuel commodities based on the forecasted usage of the thermal district energy centers. Realized gains and losses on these contracts are reflected in the fuel costs that are permitted to be billed to customers through the related customer contracts or tariffs and, accordingly, no gains or losses are reflected in the consolidated statements of income for these contracts. In 2015, certain NRG subsidiaries entered into commodity contracts with NRG Power Marketing and NRG Texas Power LLC. The purpose of these commodity contracts was to hedge the forecasted sale of power for Elbow Creek, Goat Wind, Alta X and Alta XI until the start of the PPAs. The effect of these commodity hedges was recorded to operating revenues, as described in Note 11, Related Party Transactions . For the three and nine months ended September 30, 2015 , the impact to the consolidated statements of income was an unrealized loss of $2 million and an unrealized gain of $1 million , respectively. See Note 5 , Fair Value of Financial Instruments , for a discussion regarding concentration of credit risk.

Long-term Debt

Long-term Debt	9 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
Long-term Debt	Long-term Debt This footnote should be read in conjunction with the complete description under Note 9, Long-term Debt , to the Company's consolidated financial statements included in the Company's September 6, 2016 Form 8-K. Long-term debt consisted of the following: September 30, 2016 December 31, 2015 September 30, 2016, interest rate % (a) Letters of Credit Outstanding at September 30, 2016 (In millions, except rates) 2019 Convertible Notes (b) $ 334 $ 330 3.500 2020 Convertible Notes (c) 270 266 3.250 2024 Senior Notes 500 500 5.375 2026 Senior Notes 350 — 5.000 NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility, due 2019 (d) — 306 L+2.75 $ 64 Project-level debt: Alpine, due 2022 147 154 L+1.75 37 Alta Wind I, lease financing arrangement, due 2034 245 252 7.015 16 Alta Wind II, lease financing arrangement, due 2034 194 198 5.696 23 Alta Wind III, lease financing arrangement, due 2034 201 206 6.067 23 Alta Wind IV, lease financing arrangement, due 2034 130 133 5.938 16 Alta Wind V, lease financing arrangement, due 2035 208 213 6.071 26 Alta Realty Investments, due 2031 32 33 7.000 — Alta Wind Asset Management, due 2031 18 19 L+2.375 — Avra Valley, due 2031 57 60 L+1.75 3 Blythe, due 2028 20 21 L+1.625 6 Borrego, due 2025 and 2038 70 72 L+ 2.50/5.65 5 CVSR, due 2037 771 793 2.339 - 3.775 — CVSR Holdco, due 2037 199 — 4.68 13 El Segundo Energy Center, due 2023 443 485 L+1.625 - L+2.25 82 Energy Center Minneapolis, due 2017 and 2025 98 108 5.95 -7.25 — Kansas South, due 2031 31 33 L+2.00 4 Laredo Ridge, due 2028 101 104 L+1.875 10 Marsh Landing, due 2017 and 2023 385 418 L+1.75 - L+1.875 33 PFMG and related subsidiaries financing agreement, due 2030 28 29 6.000 — Roadrunner, due 2031 37 40 L+1.625 5 South Trent Wind, due 2020 58 62 L+1.625 10 TA High Desert, due 2020 and 2032 51 52 L+2.50/5.15 8 Tapestry, due 2021 175 181 L+1.625 20 Viento, due 2023 183 189 L+2.75 27 Walnut Creek, due 2023 322 351 L+1.625 49 WCEP Holdings, due 2023 46 46 L+3.00 — Other — 2 various — Subtotal project-level debt: 4,250 4,254 Total debt 5,704 5,656 Less current maturities 281 264 Less deferred financing costs 64 63 Total long-term debt $ 5,359 $ 5,329 (a) As of September 30, 2016 , L+ equals 3 month LIBOR plus x%, except for the Alpine term loan, Marsh Landing term loan, Walnut Creek term loan, and NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility, where L+ equals 1 month LIBOR plus x% and Kansas South and Viento, where L+ equals 6 month LIBOR plus x%. (b) Net of discount of $11 million and $15 million as of September 30, 2016 , and December 31, 2015 , respectively. (c) Net of discount of $17 million and $21 million as of September 30, 2016 , and December 31, 2015 , respectively. (d) Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement. The financing arrangements listed above contain certain covenants, including financial covenants that the Company is required to be in compliance with during the term of the respective arrangement. As of September 30, 2016 , the Company was in compliance with all of the required covenants. The discussion below describes material changes to or additions of long-term debt for the nine months ended September 30, 2016 . NRG Yield Operating LLC 2026 Senior Notes On August 18, 2016, NRG Yield Operating LLC issued $350 million of senior unsecured notes, or the 2026 Senior Notes. The 2026 Senior Notes bear interest at 5.00% and mature on September 15, 2026. Interest on the notes is payable semi-annually on March 15 and September 15 of each year, and interest payments will commence on March 15, 2017. The 2026 Senior Notes are senior unsecured obligations of NRG Yield Operating LLC and are guaranteed by NRG Yield LLC, and by certain of NRG Yield Operating LLC’s wholly owned current and future subsidiaries. A portion of the proceeds of the 2026 Senior Notes were used to repay the Company's revolving credit facility, as described below. CVSR Holdco Financing Arrangement On July 15, 2016, CVSR Holdco, the indirect owner of the CVSR solar facility, issued $200 million of senior secured notes, or the 2037 Notes, that bear interest at 4.68% and mature on March 31, 2037. Net proceeds were distributed to the Company and NRG based on their respective ownership as of July 15, 2016, and accordingly, the Company received net proceeds of $97.5 million . As described in Note 3 , Business Acquisitions , on September 1, 2016, the Company acquired the remaining 51.05% of CVSR, and assumed additional debt of $496 million , which represents 51.05% of the CVSR project level debt and the 2037 Notes. In connection with the retrospective adjustment of prior periods, as described in Note 1, Nature of Business , the Company now consolidates CVSR and 100% of its debt, in all periods presented. NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility The Company borrowed $60 million from the revolving credit facility and repaid $366 million during the nine months ended September 30, 2016 . The Company used its pro rata proceeds of $97.5 million from the CVSR Holdco Financing Arrangement, as described above, along with $28 million of cash on hand, to reduce borrowings under the Company’s revolving credit facility in July 2016. Additionally, in August 2016, the Company used a portion of its proceeds from the issuance of the 2026 Senior Notes to pay the remaining revolver balance of $193 million . As of September 30, 2016 , there were no outstanding borrowings under the revolving credit facility and the Company had $64 million of letters of credit outstanding. Thermal Financing On October 31, 2016, NRG Energy Center Minneapolis LLC, a subsidiary of NRG Thermal LLC, received proceeds of $125 million from the issuance of 3.55% Series D notes due October 31, 2031, or the Series D Notes, and entered into a shelf facility for the anticipated issuance of an additional $70 million of notes. The Series D Notes are, and the additional notes, if issued, will be secured by substantially all of the assets of NRG Energy Center Minneapolis LLC. NRG Thermal LLC has guaranteed the indebtedness and its guarantee is secured by a pledge of the equity interests in all of NRG Thermal LLC’s subsidiaries. NRG Energy Center Minneapolis LLC distributed the proceeds of the Series D Notes to NRG Thermal LLC, which in turn distributed the proceeds to NRG Yield Operating LLC to be utilized for general corporate purposes, including potential acquisitions.

Earnings Per Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2016
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share Basic earnings per common share is computed by dividing net income by the weighted average number of common shares outstanding. Shares issued during the year are weighted for the portion of the year that they were outstanding. Diluted earnings per share is computed in a manner consistent with that of basic earnings per share while giving effect to all potentially dilutive common shares that were outstanding during the period. The reconciliation of the Company's basic and diluted earnings per share is shown in the following tables: Three months ended September 30, 2016 2015 (In millions, except per share data) (a) Common Class A Common Class C Common Class A Common Class C Basic earnings per share attributable to NRG Yield, Inc. common stockholders Net income attributable to NRG Yield, Inc. $ 12 $ 21 $ 6 $ 11 Weighted average number of common shares outstanding — basic 35 63 35 63 Earnings per weighted average common share — basic $ 0.34 $ 0.34 $ 0.18 $ 0.18 Diluted earnings per share attributable to NRG Yield, Inc. common stockholders Net income attributable to NRG Yield, Inc. $ 15 $ 24 $ 6 $ 11 Weighted average number of common shares outstanding — diluted 49 73 35 63 Earnings per weighted average common share — diluted $ 0.30 $ 0.32 $ 0.18 $ 0.18 Nine months ended September 30, 2016 2015 (In millions, except per share data) (a) Common Class A Common Class C Common Class A Common Class C Basic earnings per share attributable to NRG Yield, Inc. common stockholders Net income attributable to NRG Yield, Inc. $ 25 $ 45 $ 10 $ 12 Weighted average number of common shares outstanding — basic 35 63 35 44 Earnings per weighted average common share — basic $ 0.72 $ 0.72 $ 0.28 $ 0.28 Diluted earnings per share attributable to NRG Yield, Inc. common stockholders Net income attributable to NRG Yield, Inc. $ 34 $ 45 $ 10 $ 12 Weighted average number of common shares outstanding — diluted 49 63 35 44 Earnings per weighted average common share — diluted $ 0.68 $ 0.72 $ 0.28 $ 0.28 (a) Net income attributable to NRG Yield, Inc. and basic and diluted earnings per share might not recalculate due to presenting values in millions rather than whole dollars. With respect to the Class A common stock, there were a total of 15 million anti-dilutive outstanding equity instruments for the three and nine months ended September 30, 2015 , related to the 2019 Convertible Notes. With respect to the Class C common stock, there were a total of 10 million anti-dilutive outstanding equity instruments for the nine months ended September 30, 2016 and 10 million and 4 million anti-dilutive outstanding equity instruments for the three and nine months ended September 30, 2015 , respectively, related to the 2020 Convertible Notes.

Segment Reporting

Segment Reporting	9 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Segment Reporting	Segment Reporting The Company’s segment structure reflects how management currently operates and allocates resources. The Company's businesses are primarily segregated based on conventional power generation, renewable businesses which consist of solar and wind, and the thermal and chilled water business. The Corporate segment reflects the Company's corporate costs. The Company's chief operating decision maker, its Chief Executive Officer, evaluates the performance of its segments based on operational measures including adjusted earnings before interest, taxes, depreciation and amortization, or Adjusted EBITDA, and CAFD, as well as economic gross margin and net income (loss). Three months ended September 30, 2016 (In millions) Conventional Generation Renewables Thermal Corporate Total Operating revenues $ 82 $ 142 $ 48 $ — $ 272 Cost of operations 14 31 31 — 76 Depreciation and amortization 20 50 5 — 75 General and administrative — — — 4 4 Operating income (loss) 48 61 12 (4 ) 117 Equity in earnings of unconsolidated affiliates 3 10 — — 13 Other income, net 1 — — — 1 Interest expense (13 ) (37 ) (2 ) (19 ) (71 ) Income (loss) before income taxes 39 34 10 (23 ) 60 Income tax expense — — — 13 13 Net Income (Loss) $ 39 $ 34 $ 10 $ (36 ) $ 47 Total Assets $ 2,001 $ 5,783 $ 427 $ 271 $ 8,482 Three months ended September 30, 2015 (a) (In millions) Conventional Generation Renewables Thermal Corporate Total Operating revenues $ 86 $ 124 $ 46 $ — $ 256 Cost of operations 15 36 31 — 82 Depreciation and amortization 19 45 5 — 69 General and administrative — — — 3 3 Acquisition-related transaction and integration costs — — — 1 1 Operating income (loss) 52 43 10 (4 ) 101 Equity in earnings of unconsolidated affiliates 3 9 — — 12 Loss on debt extinguishment — (2 ) — — (2 ) Interest expense (11 ) (41 ) (1 ) (18 ) (71 ) Income (loss) before income taxes 44 9 9 (22 ) 40 Income tax expense — — — 8 8 Net Income (Loss) $ 44 $ 9 $ 9 $ (30 ) $ 32 (a) Retrospectively adjusted as discussed in Note 1, Nature of Business . Nine months ended September 30, 2016 (In millions) Conventional Generation Renewables Thermal Corporate Total Operating revenues $ 246 $ 412 $ 131 $ — $ 789 Cost of operations 53 98 87 — 238 Depreciation and amortization 60 149 15 — 224 General and administrative — — — 10 10 Operating income (loss) 133 165 29 (10 ) 317 Equity in earnings of unconsolidated affiliates 10 19 — — 29 Other income, net 1 2 — — 3 Interest expense (36 ) (115 ) (5 ) (57 ) (213 ) Income (loss) before income taxes 108 71 24 (67 ) 136 Income tax expense — — — 25 25 Net Income (Loss) $ 108 $ 71 $ 24 $ (92 ) $ 111 Nine months ended September 30, 2015 (a) (In millions) Conventional Generation Renewables Thermal Corporate Total Operating revenues $ 247 $ 347 $ 135 $ — $ 729 Cost of operations 51 99 96 — 246 Depreciation and amortization 61 147 14 — 222 General and administrative — — — 9 9 Acquisition-related transaction and integration costs — — — 2 2 Operating income (loss) 135 101 25 (11 ) 250 Equity in earnings of unconsolidated affiliates 10 9 — — 19 Other income, net 1 1 — — 2 Loss on debt extinguishment (7 ) (2 ) — — (9 ) Interest expense (36 ) (116 ) (5 ) (44 ) (201 ) Income (loss) before income taxes 103 (7 ) 20 (55 ) 61 Income tax expense — — — 8 8 Net Income (Loss) $ 103 $ (7 ) $ 20 $ (63 ) $ 53 (a) Retrospectively adjusted as discussed in Note 1, Nature of Business .

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes Effective Tax Rate The income tax provision consisted of the following: Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 (In millions, except percentages) Income before income taxes $ 60 $ 40 $ 136 $ 61 Income tax expense 13 8 25 8 Effective income tax rate 21.7 % 20.0 % 18.4 % 13.1 % For the three and nine months ended September 30, 2016 , and 2015 , the overall effective tax rate was different than the statutory rate of 35% primarily due to taxable earnings allocated to NRG resulting from its interest in NRG Yield LLC and production and investment tax credits generated from certain wind and solar assets, respectively. For tax purposes, NRG Yield LLC is treated as a partnership; therefore, the Company and NRG each record their respective share of taxable income or loss.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2016
Related Party Transactions [Abstract]
Related Party Transactions Disclosure	Related Party Transactions In addition to the transactions and relationships described elsewhere in these notes to the consolidated financial statements, NRG and certain subsidiaries of NRG provide services to the Company and its project entities. Amounts due to NRG subsidiaries are recorded as accounts payable - affiliate and amounts due to the Company from NRG or its subsidiaries are recorded as accounts receivable - affiliate in the Company's balance sheet. Power Hedge Contracts by and between Renewables segment Entities and NRG Certain NRG Wind TE Holdco entities, which are subsidiaries in the Renewables segment, entered into power hedge contracts with NRG Texas Power LLC and generated $17 million during the nine months ended September 30, 2015 . Effective October 2015, Elbow Creek, one of the NRG Wind TE Holdco entities, entered into a PPA with NRG Power Marketing LLC, or NRG Power Marketing, as further described below, and the hedge agreement between Elbow Creek and NRG Texas Power LLC was terminated. Additionally, Alta X and Alta XI entered into a hedge agreement with NRG Power Marketing, as further described in Note 6 , Accounting for Derivative Instruments and Hedging Activities , to hedge the forecasted sale of power until the start of the PPAs on January 1, 2016. Power Purchase Agreement by and between Elbow Creek and NRG In October 2015, Elbow Creek, the Company's subsidiary in the Renewables segment, entered into a PPA with NRG Power Marketing for the sale of energy and environmental attributes with the effective date of November 1, 2015, and expiring on October 31, 2022. Elbow Creek generated $6 million of revenue during the nine months ended September 30, 2016 . Operation and Maintenance (O&M) Services Agreements by and between Thermal Entities and NRG Certain thermal entities which are wholly-owned subsidiaries of the Company are party to a Plant O&M Services Agreement with NRG, pursuant to which NRG provides necessary and appropriate services to operate and maintain the subsidiaries' plant operations, businesses and thermal facilities. NRG is reimbursed for the provided services, as well as, for all reasonable and related expenses and expenditures, and payments to third parties for services and materials rendered to or on behalf of the parties to the agreements. NRG is not entitled to any management fee or mark-up under the agreements. Total fees incurred under the agreements were $15 million and $21 million for the nine months ended September 30, 2016 , and 2015 , respectively. There was a balance of $23 million and $29 million due to NRG in accounts payable — affiliate as of September 30, 2016 and December 31, 2015 , respectively. As of September 30, 2016 , $12 million of the balance was recorded in the current liabilities of the consolidated balance sheet and $11 million was recorded in long term liabilities of the consolidated balance sheet. Subsequent to September 30, 2016 , the Company made payments of $4 million to reduce the outstanding balance due to NRG. Power Purchase Agreement by and between NRG Energy Center Dover LLC and NRG In February 2016, NRG Energy Center Dover LLC, or NRG Dover, a subsidiary of the Company, entered into a PPA with NRG Power Marketing for the sale of energy and environmental attributes with an effective date of February 1, 2016 and expiration date of December 31, 2018. NRG Dover generated $4 million of revenue during the nine months ended September 30, 2016 . The agreement in place is in addition to the existing Power Sales and Services Agreement described further below. Power Sales and Services Agreement by and between NRG Energy Center Dover LLC and NRG NRG Dover, a subsidiary of the Company, is party to a Power Sales and Services Agreement with NRG Power Marketing. The agreement is automatically renewed on a month-to-month basis unless terminated by either party upon at least 30 days written notice. Under the agreement, NRG Power Marketing has the exclusive right to (i) manage, market and sell power, (ii) procure fuel and fuel transportation for operation of the Dover generating facility, to include for purposes other than generating power, (iii) procure transmission services required for the sale of power, and (iv) procure and market emissions credits for operation of the Dover generating facility. In addition, NRG Power Marketing has the exclusive right and obligation to direct the output from the generating facility, in accordance with and to meet the terms of any power sales contracts executed against the power generation of the Dover facility. Under the agreement, NRG Power Marketing pays NRG Dover gross receipts generated through sales, less costs incurred by NRG Power Marketing related to providing such services as transmission and delivery costs, as well as fuel costs. In July 2013, the coal-fueled plant was converted to a natural gas facility. For the nine months ended September 30, 2016 and 2015 , NRG Dover purchased $1 million and $4 million , respectively, of natural gas from NRG Power Marketing. Energy Marketing Services Agreement by and between NRG Energy Center Minneapolis LLC and NRG NRG Energy Center Minneapolis LLC, or NRG Minneapolis, a subsidiary of the Company is party to an Energy Marketing Services Agreement with NRG Power Marketing, a wholly-owned subsidiary of NRG. Under the agreement, NRG Power Marketing procures fuel and fuel transportation for the operation of the Minneapolis generating facility. For the nine months ended September 30, 2016 and 2015 , NRG Minneapolis purchased $5 million and $6 million , respectively, of natural gas from NRG Power Marketing. O&M Services Agreements by and between GenConn and NRG GenConn incurs fees under two O&M services agreements with wholly-owned subsidiaries of NRG. The fees incurred under the agreements were $4 million and $3 million for the nine months ended September 30, 2016 and 2015 , respectively. O&M Services Agreement by and between El Segundo and NRG El Segundo incurs fees under an O&M services agreement with NRG El Segundo Operations, Inc., a wholly-owned subsidiary of NRG. Under the O&M services agreement, NRG El Segundo Operations, Inc. manages, operates and maintains the El Segundo facility for an initial term of ten years following the commercial operations date. For the nine months ended September 30, 2016 and 2015 , the costs incurred under the agreement were $4 million . There was a balance of $1 million due to NRG El Segundo in accounts payable — affiliate as of September 30, 2016 and December 31, 2015 . Administrative Services Agreement by and between Marsh Landing and NRG Marsh Landing is a party to an administrative services agreement with GenOn Energy Services, LLC, a wholly-owned subsidiary of NRG, which provides invoice processing and payment on behalf of Marsh Landing. Marsh Landing reimburses GenOn Energy Services, LLC for the amounts paid by it. The Company reimbursed costs under this agreement of $9 million and $11 million for the nine months ended September 30, 2016 and 2015 , respectively. There was a balance of $1 million and $6 million due to GenOn Energy Services, LLC in accounts payable — affiliate as of September 30, 2016 and December 31, 2015 , respectively. Administrative Services Agreement by and between CVSR and NRG CVSR is a party to an administrative services agreement with NRG Renew Operation & Maintenance LLC, a wholly-owned subsidiary of NRG, which provides O&M services on behalf of CVSR. Initially, the agreement was entered into with NRG Energy Services and was subsequently assigned to NRG Renew Operation & Maintenance LLC on July 15, 2015. The Company reimbursed a total of $2 million and $4 million to both entities for the expenses incurred for the nine months ended September 30, 2016 and 2015 , respectively. Management Services Agreement by and between the Company and NRG NRG provides the Company with various operation, management, and administrative services, which include human resources, accounting, tax, legal, information systems, treasury, and risk management, as set forth in the Management Services Agreement. As of September 30, 2016 , the base management fee was approximately $7.5 million per year, subject to an inflation-based adjustment annually at an inflation factor based on the year-over-year U.S. consumer price index. The fee is also subject to adjustments following the consummation of future acquisitions and as a result of a change in the scope of services provided under the Management Services Agreement. During the nine months ended September 30, 2016 , the fee was increased by $0.5 million on an annual basis primarily due to the acquisition of the CVSR Drop Down. Costs incurred under this agreement were $7 million for the nine months ended September 30, 2016 and 2015 , which included certain direct expenses incurred by NRG on behalf of the Company in addition to the base management fee. There was a balance of $3 million due to NRG in accounts payable — affiliate as of September 30, 2016 . Subsequent to September 30, 2016 , the balance has been paid in full. Administrative Services Agreements by and between NRG Wind TE Holdco and NRG Certain subsidiaries of NRG have entered into agreements with the Company's project entities to provide operation and maintenance services for the balance of the plants not covered by turbine supplier's maintenance and service agreements for the post-warranty period. The agreements have various terms with provisions for extension until terminated. For the nine months ended September 30, 2016 and 2015 , the costs incurred under the agreements were $4 million and $3 million , respectively. Certain subsidiaries of NRG provide support services to the NRG Wind TE Holdco project entities pursuant to various support services agreements. The agreements provide for administrative and support services and reimbursements of certain insurance, consultant, and credit costs. For the nine months ended September 30, 2016 and 2015 , the costs incurred under the agreements were $2 million .

Contingencies (Notes)

Contingencies (Notes)	9 Months Ended
	Sep. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Contingencies Disclosure [Text Block]	Contingencies The Company's material legal proceedings are described below. The Company believes that it has valid defenses to these legal proceedings and intends to defend them vigorously. The Company records reserves for estimated losses from contingencies when information available indicates that a loss is probable and the amount of the loss, or range of loss, can be reasonably estimated. In addition, legal costs are expensed as incurred. Management assesses such matters based on current information and makes a judgment concerning its potential outcome, considering the nature of the claim, the amount and nature of damages sought, and the probability of success. The Company is unable to predict the outcome of the legal proceedings below or reasonably estimate the scope or amount of any associated costs and potential liabilities. As additional information becomes available, management adjusts its assessment and estimates of such contingencies accordingly. Because litigation is subject to inherent uncertainties and unfavorable rulings or developments, it is possible that the ultimate resolution of the Company's liabilities and contingencies could be at amounts that are different from its currently recorded reserves and that such difference could be material. In addition to the legal proceedings noted below, the Company and its subsidiaries are party to other litigation or legal proceedings arising in the ordinary course of business. In management's opinion, the disposition of these ordinary course matters will not materially adversely affect the Company's consolidated financial position, results of operations, or cash flows. Braun v. NRG Yield, Inc. — On April 19, 2016, plaintiffs filed a putative class action lawsuit against NRG Yield, Inc., the current and former members of its board of directors individually, and other parties in California Superior Court in Kern County, CA. Plaintiffs allege various violations of the Securities Act due to the defendants’ alleged failure to disclose material facts related to low wind production prior to NRG Yield, Inc.'s June 22, 2015 Class C common stock offering. Plaintiffs seek compensatory damages, rescission, attorney’s fees and costs. On August 3, 2016, the court approved a stipulation entered into by the parties. The stipulation provided that the plaintiffs would file an amended complaint by August 19, 2016, which they did on August 18, 2016. The defendants filed demurrers and a motion challenging jurisdiction on October 18, 2016. Ahmed v. NRG Energy, Inc. and the NRG Yield Board of Directors — On September 15, 2016, plaintiffs filed a putative class action lawsuit against NRG Energy, Inc., the directors of NRG Yield, Inc., and other parties in the Delaware Chancery Court. The complaint alleges that the defendants breached their respective fiduciary duties with regard to the recapitalization of NRG Yield, Inc. common stock in 2015. The plaintiffs generally seek economic damages, attorney’s fees and injunctive relief. The defendants filed responsive pleadings on November 4, 2016.

Summary of Significant Accoun20

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
Use of Estimates	Use of Estimates The preparation of consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions. These estimates and assumptions impact the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities as of the date of the consolidated financial statements, and the reported amounts of revenues and expenses during the reporting period. Actual results could be different from these estimates.
Noncontrolling Interest Disclosure [Text Block]	Noncontrolling Interests The following table reflects the changes in the Company's noncontrolling interest balance: (In millions) Balance as of December 31, 2015 $ 897 Capital contributions from tax equity investors, net of distributions 7 November 2015 Drop Down Assets working capital payment 2 Payment for CVSR Drop Down (79 ) Pre-acquisition net income of Drop Down Assets 10 Comprehensive income 16 Distributions to NRG for Drop Down Assets (172 ) Yield LLC distributions to NRG (59 ) Balance as of September 30, 2016 $ 622 Distributions to NRG for Drop Down Assets Distributions to NRG for Drop Down Assets relate to NRG's 25% interest in the November 2015 Drop Down Assets as well as NRG's 51.05% interest in CVSR prior to its acquisition by the Company. This amount includes cash and non-cash distributions and includes portion of the proceeds from the senior notes issued under the CVSR Holdco Financing Arrangement on July 15, 2016, as described in Note 7, Long-term Debt . Yield LLC Distributions to NRG The following table lists the distributions paid on NRG Yield LLC's Class B and D units during the nine months ended September 30, 2016 : Third Quarter 2016 Second Quarter 2016 First Quarter 2016 Distributions per Class B Unit 0.24 $ 0.23 $ 0.225 Distributions per Class D Unit 0.24 $ 0.23 $ 0.225 On November 2, 2016 , NRG Yield LLC declared a distribution on its units of $0.25 per unit payable on December 15, 2016 to unit holders of record as of December 1, 2016 .
Distributions [Policy Text Block]	Distributions to NRG The following table lists the distributions paid on NRG Yield LLC's Class B and D units during the nine months ended September 30, 2016 : Third Quarter 2016 Second Quarter 2016 First Quarter 2016 Distributions per Class B Unit 0.24 $ 0.23 $ 0.225 Distributions per Class D Unit 0.24 $ 0.23 $ 0.225 On November 2, 2016 , NRG Yield LLC declared a distribution on its units of $0.25 per unit payable on December 15, 2016 to unit holders of record as of December 1, 2016 . Reclassifications Certain prior-year amounts have been reclassified for comparative
Recent Accounting Developments	purposes. Recent Accounting Developments ASU 2016-16 - In October 2016, the FASB issued ASU No. 2016-16, Income Taxes (Topic 740) , Intra-Entity Transfers of Assets Other Than Inventory, or ASU No. 2016-16. The amendments of ASU No. 2016-16 were issued to improve the accounting for the income tax consequences of intra-entity transfers of assets other than inventory. Current GAAP prohibits the recognition of current and deferred income taxes for an intra-entity asset transfer until the asset has been sold to an outside party which has resulted in diversity in practice and increased complexity within financial reporting. The amendments of ASU No. 2016-16 would require an entity to recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs and do not require new disclosure requirements. The amendments of ASU No. 2016-16 are effective for annual reporting periods beginning after December 15, 2017, and interim periods within those annual periods. Early adoption is permitted and the adoption of ASU No. 2016-16 should be applied on a modified retrospective basis through a cumulative-effect adjustment directly to retained earnings as of the beginning of the period of adoption. The Company is currently evaluating the impact of the standard on the Company’s results of operations, cash flows and financial position. ASU 2016-15 — In August 2016, the FASB issued ASU No. 2016-15, Statement of Cash Flows (Topic 230) , Classification of Certain Cash Receipts and Cash Payments, or ASU No. 2016-15. The amendments of ASU No. 2016-15 were issued to address eight specific cash flow issues for which stakeholders have indicated to the FASB that a diversity in practice existed in how entities were presenting and classifying these items in the statement of cash flows. The issues addressed by ASU No. 2016-15 include but are not limited to the classification of debt prepayment and debt extinguishment costs, payments made for contingent consideration for a business combination, proceeds from the settlement of insurance proceeds, distributions received from equity method investees and separately identifiable cash flows and the application of the predominance principle. The amendments of ASU No. 2016-15 are effective for public entities for fiscal years beginning after December 15, 2017 and interim periods in those fiscal years. Early adoption is permitted, including adoption in an interim fiscal period with all amendments adopted in the same period. The adoption of ASU No. 2016-15 is required to be applied retrospectively. The Company is currently evaluating the impact of the standard on the Company's statement of cash flows. ASU 2016-07 — In March 2016, the FASB issued ASU No. 2016-07, Investments - Equity Method and Joint Ventures (Topic 323), or ASU No. 2016-07. The amendments of ASU No. 2016-07 eliminate the requirement that when an investment qualifies for use of the equity method as a result of an increase in the level of ownership interest or degree of influence, an investor must adjust the investment, results of operations, and retained earnings retroactively on a step-by-step basis as if the equity method had been in effect during all previous periods that the investment had been held. The amendments require that the equity method investor add the cost of acquiring the additional interest in the investee to the current basis of the investor's previously held interest and adopt the equity method of accounting with no retroactive adjustment to the investment. In addition, ASU No. 2016-07 requires that an entity that has an available-for-sale equity security that becomes qualified for the equity method of accounting recognize through earnings the unrealized holding gain or loss in accumulated other comprehensive income at the date the investment becomes qualified for use of the equity method. The guidance in ASU No. 2016-07 is effective for fiscal years beginning after December 15, 2016, and interim periods within those annual periods. The adoption of ASU No. 2016-07 is required to be applied prospectively and early adoption is permitted. The Company does not expect the standard to have a material impact on its results of operations, cash flows and financial position. ASU 2016-02 — In February 2016, the FASB issued ASU No. 2016-02, Leases (Topic 842), or ASU No. 2016-02. The amendments of ASU No. 2016-02 complete the joint effort between the FASB and the International Accounting Standards Board, or IASB, to develop a common leasing standard for GAAP and International Financial Reporting Standards, or IFRS, with the objective to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and to improve financial reporting. The guidance in ASU No. 2016-02 provides that a lessee that may have previously accounted for a lease as an operating lease under current GAAP should recognize the assets and liabilities that arise from a lease on the balance sheet. In addition, ASU No. 2016-02 expands the required quantitative and qualitative disclosures with regards to lease arrangements. The guidance in ASU No. 2016-02 is effective for fiscal years beginning after December 15, 2018, and interim periods within those annual periods. The adoption of ASU No. 2016-02 is required to be applied using a modified retrospective approach for the earliest period presented and early adoption is permitted. The Company is currently working through an adoption plan which includes the evaluation of lease contracts compared to the new standard and evaluating the impact of ASU No.2016-02 on the Company's results of operations, cash flows and financial position. ASU 2016-01 — In January 2016, the FASB issued ASU No. 2016-01, Financial Instruments - Overall (Subtopic 825-10): Recognition and Measurement of Financial Assets and Financial Liabilities , or ASU No. 2016-01. The amendments of ASU No. 2016-01 eliminate available-for-sale classification of equity investments and require that equity investments (except those accounted for under the equity method of accounting, or those that result in consolidation of the investee) to be generally measured at fair value with changes in fair value recognized in net income. Further, the amendments require financial assets and financial liabilities to be presented separately in the notes to the financial statements, grouped by measurement category and form of financial asset. The guidance in ASU No. 2016-01 is effective for financial statements issued for fiscal years beginning after December 15, 2017, and interim periods within those annual periods. The Company is currently evaluating the impact of the standard on the Company's results of operations, cash flows and financial position. ASU 2015-16 — In September 2015, the FASB issued ASU No. 2015-16, Business Combinations (Topic 805): Simplifying the Accounting for Measurement-Period Adjustments , or ASU No. 2015-16. The amendments of ASU No. 2015-16 require that an acquirer recognize measurement period adjustments to the provisional amounts recognized in a business combination in the reporting period during which the adjustments are determined. Additionally, the amendments of ASU No. 2015-16 require the acquirer to record in the same period's financial statements the effect on earnings of changes in depreciation, amortization or other income effects, if any, as a result of the measurement period adjustment, calculated as if the accounting had been completed at the acquisition date as well as disclosing on either the face of the income statement or in the notes the portion of the amount recorded in current period earnings that would have been recorded in previous reporting periods. The guidance in ASU No. 2015-16 is effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. The amendments should be applied prospectively. The Company adopted this standard on January 1, 2016, and the adoption of this standard did not impact the Company's results of operations, cash flows or financial position. ASU 2014-09 — In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers (Topic 606), or ASU No. 2014-09. The amendments of ASU No. 2014-09 complete the joint effort between the FASB and the IASB, to develop a common revenue standard for GAAP and IFRS, and to improve financial reporting. In addition to ASU No. 2014-09, the FASB has issued additional guidance which provides further clarification on Topic 606 including ASU No. 2016-08, ASU No. 2016-10, ASU No. 2016-12. The guidance under Topic 606 provides that an entity should recognize revenue to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled to in exchange for the goods or services provided and establishes a four step process to be applied by an entity in evaluating its contracts with customers. In August 2015, the FASB issued ASU No. 2015-14, which formally deferred the effective date by one year to make the guidance of ASU No. 2014-09 effective for annual reporting periods beginning after December 15, 2017, including interim periods therein. Early adoption is permitted, but not prior to the original effective date, which was for annual reporting periods beginning after December 15, 2016. The Company is working through an adoption plan which includes the evaluation of revenue contracts compared to the new standard and evaluating the impact of Topic 606 on the Company' results of operations, cash flows and financial position.

Segment Reporting Segment Repor

Segment Reporting Segment Reporting (Policies)	9 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Segment Reporting, Policy [Policy Text Block]	The Company’s segment structure reflects how management currently operates and allocates resources. The Company's businesses are primarily segregated based on conventional power generation, renewable businesses which consist of solar and wind, and the thermal and chilled water business. The Corporate segment reflects the Company's corporate costs. The Company's chief operating decision maker, its Chief Executive Officer, evaluates the performance of its segments based on operational measures including adjusted earnings before interest, taxes, depreciation and amortization, or Adjusted EBITDA, and CAFD, as well as economic gross margin and net income (loss).

Nature of Business Nature of Bu

Nature of Business Nature of Business (Tables)	9 Months Ended
	Sep. 30, 2016
Nature of Business Disclosure [Abstract]
IPO of NRG Yield	The following table represents the structure of the Company as of September 30, 2016 :
Schedule of Ownership	As of September 30, 2016 , the Company's operating assets are comprised of the following projects: Projects Percentage Ownership Net Capacity (MW) (a) Offtake Counterparty Expiration Conventional El Segundo 100 % 550 Southern California Edison 2023 GenConn Devon 50 % 95 Connecticut Light & Power 2040 GenConn Middletown 50 % 95 Connecticut Light & Power 2041 Marsh Landing 100 % 720 Pacific Gas and Electric 2023 Walnut Creek 100 % 485 Southern California Edison 2023 1,945 Utility Scale Solar Alpine 100 % 66 Pacific Gas and Electric 2033 Avenal 50 % 23 Pacific Gas and Electric 2031 Avra Valley 100 % 26 Tucson Electric Power 2032 Blythe 100 % 21 Southern California Edison 2029 Borrego 100 % 26 San Diego Gas and Electric 2038 CVSR 100 % 250 Pacific Gas and Electric 2038 Desert Sunlight 250 25 % 63 Southern California Edison 2035 Desert Sunlight 300 25 % 75 Pacific Gas and Electric 2040 Kansas South 100 % 20 Pacific Gas and Electric 2033 Roadrunner 100 % 20 El Paso Electric 2031 TA High Desert 100 % 20 Southern California Edison 2033 610 Distributed Solar AZ DG Solar Projects 100 % 5 Various 2025 - 2033 PFMG DG Solar Projects 51 % 4 Various 2032 9 Wind Alta I 100 % 150 Southern California Edison 2035 Alta II 100 % 150 Southern California Edison 2035 Alta III 100 % 150 Southern California Edison 2035 Alta IV 100 % 102 Southern California Edison 2035 Alta V 100 % 168 Southern California Edison 2035 Alta X (b) 100 % 137 Southern California Edison 2038 Alta XI (b) 100 % 90 Southern California Edison 2038 Buffalo Bear 100 % 19 Western Farmers Electric Co-operative 2033 Crosswinds 74.3 % 16 Corn Belt Power Cooperative 2027 Elbow Creek 75 % 92 NRG Power Marketing LLC 2022 Elkhorn Ridge 50.3 % 41 Nebraska Public Power District 2029 Forward 75 % 22 Constellation NewEnergy, Inc. 2017 Goat Wind 74.9 % 113 Dow Pipeline Company 2025 Hardin 74.3 % 11 Interstate Power and Light Company 2027 Laredo Ridge 100 % 80 Nebraska Public Power District 2031 Lookout 75 % 29 Southern Maryland Electric Cooperative 2030 Odin 74.9 % 15 Missouri River Energy Services 2028 Pinnacle 100 % 55 Maryland Department of General Services and University System of Maryland 2031 San Juan Mesa 56.3 % 68 Southwestern Public Service Company 2025 Sleeping Bear 75 % 71 Public Service Company of Oklahoma 2032 South Trent 100 % 101 AEP Energy Partners 2029 Spanish Fork 75 % 14 PacifiCorp 2028 Spring Canyon II (b) 90.1 % 29 Platte River Power Authority 2039 Spring Canyon III (b) 90.1 % 25 Platte River Power Authority 2039 Taloga 100 % 130 Oklahoma Gas & Electric 2031 Wildorado 74.9 % 121 Southwestern Public Service Company 2027 1,999 Projects Percentage Ownership Net Capacity (MW) (a) Offtake Counterparty Expiration Thermal Thermal equivalent MWt (c) 100 % 1,315 Various Various NRG Dover Energy Center LLC 100 % 103 NRG Power Marketing LLC 2018 Thermal generation 100 % 20 Various Various 1,438 Total net capacity (excluding equivalent MWt) (d) 4,686 (a) Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2016 . (b) Projects are part of tax equity arrangements. (c) For thermal energy, net capacity represents MWt for steam or chilled water and excludes 134 MWt available under the right-to-use provisions contained in agreements between two of the Company's thermal facilities and certain of its customers. (d) Total net capacity excludes 43 MW for RPV Holdco and 52 MW for DGPV Holdco 1 and DGPV Holdco 2 projects, of which the Company's net interests are 41 MW and 49 , respectively, based on cash to be distributed. These projects are part of tax equity arrangements and are consolidated by NRG, as further described in Note 4 , Variable Interest Entities, or VIEs .

Summary of Significant Accoun23

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2016
Accounting Policies [Abstract]
Schedule of Accumulated Depreciation and Amortization [Table Text Block]	The following table presents the accumulated depreciation included in the property, plant and equipment, net, and accumulated amortization included in intangible assets, net, respectively, as of September 30, 2016 and December 31, 2015: September 30, 2016 December 31, 2015 (In millions) Property, Plant and Equipment Accumulated Depreciation $ 1,002 $ 782 Intangible Assets Accumulated Amortization 151 93
Schedule of Change in Noncontrolling Interest [Table Text Block]	The following table reflects the changes in the Company's noncontrolling interest balance: (In millions) Balance as of December 31, 2015 $ 897 Capital contributions from tax equity investors, net of distributions 7 November 2015 Drop Down Assets working capital payment 2 Payment for CVSR Drop Down (79 ) Pre-acquisition net income of Drop Down Assets 10 Comprehensive income 16 Distributions to NRG for Drop Down Assets (172 ) Yield LLC distributions to NRG (59 ) Balance as of September 30, 2016 $ 622
Distributions Made to Limited Liability Company (LLC) Member, by Distribution [Table Text Block]	The following table lists the distributions paid on NRG Yield LLC's Class B and D units during the nine months ended September 30, 2016 : Third Quarter 2016 Second Quarter 2016 First Quarter 2016 Distributions per Class B Unit 0.24 $ 0.23 $ 0.225 Distributions per Class D Unit 0.24 $ 0.23 $ 0.225

Business Acquisitions Business

Business Acquisitions Business Acquisitions (Tables)	9 Months Ended
	Sep. 30, 2016
CVSR [Member]
Business Acquisition [Line Items]
Schedule of Business Acquisitions, by Acquisition [Table Text Block]	The following is the summary of historical net liabilities assumed in connection with the CVSR Drop Down as of September 1, 2016: CVSR (In millions) Current assets $ 95 Property, plant and equipment 826 Non-current assets 13 Total assets 934 Debt (a) 966 Other current and non-current liabilities 12 Total liabilities 978 Net liabilities assumed (44 ) Accumulated Other Comprehensive Loss (25 ) Historical Net Liabilities Assumed $ (19 ) (a) Net of deferred financing costs of $5 million .

Variable Interest Entities (Tab

Variable Interest Entities (Tables)	9 Months Ended
	Sep. 30, 2016
Schedule of Equity Method Investments [Line Items]
Schedule of Variable Interest Entities [Table Text Block]	Summarized financial information for the Company's consolidated VIEs consisted of the following as of September 30, 2016 : (In millions) NRG Wind TE Holdco Alta Wind TE Holdco Spring Canyon Other current and non-current assets $ 189 $ 19 $ 4 Property, plant and equipment 635 466 101 Intangible assets 2 278 — Total assets 826 763 105 Current and non-current liabilities 225 9 6 Total liabilities 225 9 6 Noncontrolling interest 209 118 69 Net assets less noncontrolling interests $ 392 $ 636 $ 30
GCE Holding LLC [Member]
Schedule of Equity Method Investments [Line Items]
Summarized financial information of equity method investment	The following table presents summarized financial information for GCE Holding LLC: Three months ended September 30, Nine months ended September 30, (In millions) 2016 2015 2016 2015 Income Statement Data: Operating revenues $ 18 $ 21 $ 54 $ 61 Operating income 9 9 28 29 Net income $ 7 $ 6 $ 20 $ 20 September 30, 2016 December 31, 2015 Balance Sheet Data: (In millions) Current assets $ 29 $ 36 Non-current assets 403 416 Current liabilities 12 16 Non-current liabilities $ 208 $ 215

Fair Value of Financial Instr26

Fair Value of Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2016
Fair Value Disclosures [Abstract]
Estimated carrying values and fair values	The estimated carrying amounts and fair values of the Company’s recorded financial instruments not carried at fair market value are as follows: As of September 30, 2016 As of December 31, 2015 Carrying Amount Fair Value Carrying Amount Fair Value (In millions) Assets: Notes receivable, including current portion $ 35 $ 35 $ 47 $ 47 Liabilities: Long-term debt, including current portion $ 5,704 $ 5,729 $ 5,656 $ 5,538
Fair Value, Option, Quantitative Disclosures [Table Text Block]	The fair value of the Company's publicly-traded long-term debt is based on quoted market prices and is classified as Level 2 within the fair value hierarchy. The fair value of debt securities, non-publicly traded long-term debt and certain notes receivable of the Company are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments with equivalent credit quality and are classified as Level 3 within the fair value hierarchy. The following table presents the level within the fair value hierarchy for long-term debt, including current portion as of September 30, 2016 and December 31, 2015: As of September 30, 2016 As of December 31, 2015 Level 2 Level 3 Level 2 Level 3 (In millions) Long-term debt, including current portion $ 1,478 $ 4,251 $ 978 $ 4,560
Schedule of Fair Value, Assets and Liabilities [Table Text Block]	The Company records its derivative assets and liabilities at fair value on its consolidated balance sheet. There were no derivative asset positions on the Company's consolidated balance sheet as of December 31, 2015 . The following table presents assets and liabilities measured and recorded at fair value on the Company's consolidated balance sheets on a recurring basis and their level within the fair value hierarchy: As of September 30, 2016 As of December 31, 2015 Fair Value (a) Fair Value (a) (In millions) Level 2 Level 2 Derivative assets: Commodity contracts $ 1 $ — Total assets 1 — Derivative liabilities: Commodity contracts 1 2 Interest rate contracts 138 98 Total liabilities $ 139 $ 100 (a) There were no derivative assets or liabilities classified as Level 1 or Level 3 as of September 30, 2016 , and December 31, 2015 .

Accounting for Derivative Ins27

Accounting for Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Net notional volume buy/(sell) of NRG Yield's open derivative transactions broken out by commodity	The following table summarizes the net notional volume buy/(sell) of the Company's open derivative transactions broken out by commodity: Total Volume September 30, 2016 December 31, 2015 Commodity Units (In millions) Natural Gas MMBtu 3 4 Interest Dollars $ 1,875 $ 1,991
Fair value within the derivative instrument valuation on the balance sheets	he following table summarizes the fair value within the derivative instrument valuation on the balance sheet: Fair Value Derivative Assets Derivative Liabilities September 30, 2016 September 30, 2016 December 31, 2015 (In millions) Derivatives Designated as Cash Flow Hedges: Interest rate contracts current $ — $ 29 $ 34 Interest rate contracts long-term — 94 56 Total Derivatives Designated as Cash Flow Hedges — 123 90 Derivatives Not Designated as Cash Flow Hedges: Interest rate contracts current — 2 3 Interest rate contracts long-term — 13 5 Commodity contracts current 1 1 2 Total Derivatives Not Designated as Cash Flow Hedges 1 16 10 Total Derivatives $ 1 $ 139 $ 100
Offsetting of derivatives by counterparty master agreement level and collateral received or paid
Effects of NRG Yield's accumulated OCI balance attributable to interest rate swaps designated as cash flow hedge derivatives, net of tax	The following table summarizes the effects on the Company’s accumulated OCL balance attributable to interest rate swaps designated as cash flow hedge derivatives, net of tax: Three months ended September 30, Nine months ended September 30, 2016 2015 (a) 2016 2015 (a) (In millions) Accumulated OCL beginning balance $ (140 ) $ (73 ) $ (83 ) $ (76 ) Reclassified from accumulated OCL to income due to realization of previously deferred amounts 4 5 10 12 Mark-to-market of cash flow hedge accounting contracts 17 (36 ) (46 ) (40 ) Accumulated OCL ending balance, net of income tax benefit of $29 and $19, respectively (119 ) (104 ) (119 ) (104 ) Accumulated OCL attributable to noncontrolling interests (71 ) (72 ) (71 ) (72 ) Accumulated OCL attributable to NRG Yield, Inc. $ (48 ) $ (32 ) $ (48 ) $ (32 ) Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $4 $ 16 $ 16

Long-term Debt (Tables)

Long-term Debt (Tables)	9 Months Ended
	Sep. 30, 2016
Debt Disclosure [Abstract]
Schedule of long-term debt	Long-term debt consisted of the following: September 30, 2016 December 31, 2015 September 30, 2016, interest rate % (a) Letters of Credit Outstanding at September 30, 2016 (In millions, except rates) 2019 Convertible Notes (b) $ 334 $ 330 3.500 2020 Convertible Notes (c) 270 266 3.250 2024 Senior Notes 500 500 5.375 2026 Senior Notes 350 — 5.000 NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility, due 2019 (d) — 306 L+2.75 $ 64 Project-level debt: Alpine, due 2022 147 154 L+1.75 37 Alta Wind I, lease financing arrangement, due 2034 245 252 7.015 16 Alta Wind II, lease financing arrangement, due 2034 194 198 5.696 23 Alta Wind III, lease financing arrangement, due 2034 201 206 6.067 23 Alta Wind IV, lease financing arrangement, due 2034 130 133 5.938 16 Alta Wind V, lease financing arrangement, due 2035 208 213 6.071 26 Alta Realty Investments, due 2031 32 33 7.000 — Alta Wind Asset Management, due 2031 18 19 L+2.375 — Avra Valley, due 2031 57 60 L+1.75 3 Blythe, due 2028 20 21 L+1.625 6 Borrego, due 2025 and 2038 70 72 L+ 2.50/5.65 5 CVSR, due 2037 771 793 2.339 - 3.775 — CVSR Holdco, due 2037 199 — 4.68 13 El Segundo Energy Center, due 2023 443 485 L+1.625 - L+2.25 82 Energy Center Minneapolis, due 2017 and 2025 98 108 5.95 -7.25 — Kansas South, due 2031 31 33 L+2.00 4 Laredo Ridge, due 2028 101 104 L+1.875 10 Marsh Landing, due 2017 and 2023 385 418 L+1.75 - L+1.875 33 PFMG and related subsidiaries financing agreement, due 2030 28 29 6.000 — Roadrunner, due 2031 37 40 L+1.625 5 South Trent Wind, due 2020 58 62 L+1.625 10 TA High Desert, due 2020 and 2032 51 52 L+2.50/5.15 8 Tapestry, due 2021 175 181 L+1.625 20 Viento, due 2023 183 189 L+2.75 27 Walnut Creek, due 2023 322 351 L+1.625 49 WCEP Holdings, due 2023 46 46 L+3.00 — Other — 2 various — Subtotal project-level debt: 4,250 4,254 Total debt 5,704 5,656 Less current maturities 281 264 Less deferred financing costs 64 63 Total long-term debt $ 5,359 $ 5,329 (a) As of September 30, 2016 , L+ equals 3 month LIBOR plus x%, except for the Alpine term loan, Marsh Landing term loan, Walnut Creek term loan, and NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility, where L+ equals 1 month LIBOR plus x% and Kansas South and Viento, where L+ equals 6 month LIBOR plus x%. (b) Net of discount of $11 million and $15 million as of September 30, 2016 , and December 31, 2015 , respectively. (c) Net of discount of $17 million and $21 million as of September 30, 2016 , and December 31, 2015 , respectively. (d) Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement.

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2016
Earnings Per Share [Abstract]
Schedule of Earnings Per Share, Basic and Diluted	The reconciliation of the Company's basic and diluted earnings per share is shown in the following tables: Three months ended September 30, 2016 2015 (In millions, except per share data) (a) Common Class A Common Class C Common Class A Common Class C Basic earnings per share attributable to NRG Yield, Inc. common stockholders Net income attributable to NRG Yield, Inc. $ 12 $ 21 $ 6 $ 11 Weighted average number of common shares outstanding — basic 35 63 35 63 Earnings per weighted average common share — basic $ 0.34 $ 0.34 $ 0.18 $ 0.18 Diluted earnings per share attributable to NRG Yield, Inc. common stockholders Net income attributable to NRG Yield, Inc. $ 15 $ 24 $ 6 $ 11 Weighted average number of common shares outstanding — diluted 49 73 35 63 Earnings per weighted average common share — diluted $ 0.30 $ 0.32 $ 0.18 $ 0.18 Nine months ended September 30, 2016 2015 (In millions, except per share data) (a) Common Class A Common Class C Common Class A Common Class C Basic earnings per share attributable to NRG Yield, Inc. common stockholders Net income attributable to NRG Yield, Inc. $ 25 $ 45 $ 10 $ 12 Weighted average number of common shares outstanding — basic 35 63 35 44 Earnings per weighted average common share — basic $ 0.72 $ 0.72 $ 0.28 $ 0.28 Diluted earnings per share attributable to NRG Yield, Inc. common stockholders Net income attributable to NRG Yield, Inc. $ 34 $ 45 $ 10 $ 12 Weighted average number of common shares outstanding — diluted 49 63 35 44 Earnings per weighted average common share — diluted $ 0.68 $ 0.72 $ 0.28 $ 0.28

Segment Reporting (Tables)

Segment Reporting (Tables)	9 Months Ended
	Sep. 30, 2016
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	Three months ended September 30, 2016 (In millions) Conventional Generation Renewables Thermal Corporate Total Operating revenues $ 82 $ 142 $ 48 $ — $ 272 Cost of operations 14 31 31 — 76 Depreciation and amortization 20 50 5 — 75 General and administrative — — — 4 4 Operating income (loss) 48 61 12 (4 ) 117 Equity in earnings of unconsolidated affiliates 3 10 — — 13 Other income, net 1 — — — 1 Interest expense (13 ) (37 ) (2 ) (19 ) (71 ) Income (loss) before income taxes 39 34 10 (23 ) 60 Income tax expense — — — 13 13 Net Income (Loss) $ 39 $ 34 $ 10 $ (36 ) $ 47 Total Assets $ 2,001 $ 5,783 $ 427 $ 271 $ 8,482 Three months ended September 30, 2015 (a) (In millions) Conventional Generation Renewables Thermal Corporate Total Operating revenues $ 86 $ 124 $ 46 $ — $ 256 Cost of operations 15 36 31 — 82 Depreciation and amortization 19 45 5 — 69 General and administrative — — — 3 3 Acquisition-related transaction and integration costs — — — 1 1 Operating income (loss) 52 43 10 (4 ) 101 Equity in earnings of unconsolidated affiliates 3 9 — — 12 Loss on debt extinguishment — (2 ) — — (2 ) Interest expense (11 ) (41 ) (1 ) (18 ) (71 ) Income (loss) before income taxes 44 9 9 (22 ) 40 Income tax expense — — — 8 8 Net Income (Loss) $ 44 $ 9 $ 9 $ (30 ) $ 32 (a) Retrospectively adjusted as discussed in Note 1, Nature of Business . Nine months ended September 30, 2016 (In millions) Conventional Generation Renewables Thermal Corporate Total Operating revenues $ 246 $ 412 $ 131 $ — $ 789 Cost of operations 53 98 87 — 238 Depreciation and amortization 60 149 15 — 224 General and administrative — — — 10 10 Operating income (loss) 133 165 29 (10 ) 317 Equity in earnings of unconsolidated affiliates 10 19 — — 29 Other income, net 1 2 — — 3 Interest expense (36 ) (115 ) (5 ) (57 ) (213 ) Income (loss) before income taxes 108 71 24 (67 ) 136 Income tax expense — — — 25 25 Net Income (Loss) $ 108 $ 71 $ 24 $ (92 ) $ 111 Nine months ended September 30, 2015 (a) (In millions) Conventional Generation Renewables Thermal Corporate Total Operating revenues $ 247 $ 347 $ 135 $ — $ 729 Cost of operations 51 99 96 — 246 Depreciation and amortization 61 147 14 — 222 General and administrative — — — 9 9 Acquisition-related transaction and integration costs — — — 2 2 Operating income (loss) 135 101 25 (11 ) 250 Equity in earnings of unconsolidated affiliates 10 9 — — 19 Other income, net 1 1 — — 2 Loss on debt extinguishment (7 ) (2 ) — — (9 ) Interest expense (36 ) (116 ) (5 ) (44 ) (201 ) Income (loss) before income taxes 103 (7 ) 20 (55 ) 61 Income tax expense — — — 8 8 Net Income (Loss) $ 103 $ (7 ) $ 20 $ (63 ) $ 53 (a) Retrospectively adjusted as discussed in Note 1, Nature of Business .

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2016
Income Tax Disclosure [Abstract]
Reconciliation of the U.S. federal statutory rate to the Company's effective rate	The income tax provision consisted of the following: Three months ended September 30, Nine months ended September 30, 2016 2015 2016 2015 (In millions, except percentages) Income before income taxes $ 60 $ 40 $ 136 $ 61 Income tax expense 13 8 25 8 Effective income tax rate 21.7 % 20.0 % 18.4 % 13.1 %

Nature of Business (Details)

Nature of Business (Details) $ in Millions

Sep. 02, 2016USD ($)

Feb. 19, 2016USD ($)

Nov. 03, 2015USD ($)

Jun. 29, 2015USD ($)shares

Jan. 02, 2015USD ($)

Sep. 30, 2016USD ($)MW

Sep. 30, 2015USD ($)

[1]

Sep. 01, 2016

Aug. 31, 2016

Nov. 02, 2015MW

Nature of Business

Proceeds from the issuance of common stock | $

$ 0

$ 599

Megawatts Thermal Equivalent, Available Under right-to-use Provisions

134

Equity Method Investment, Ownership Percentage

48.95%

Power Generation Capacity, Megawatts

[2]

4,686

Conventional Generation [Member]

Nature of Business

Power Generation Capacity, Megawatts

[2]

1,945

Utility-Scale Solar

Nature of Business

Power Generation Capacity, Megawatts

[2]

610

Distributed Solar [Member]

Nature of Business

Power Generation Capacity, Megawatts

[2]

9

Wind Farms [Member]

Nature of Business

Power Generation Capacity, Megawatts

[2]

1,999

Thermal [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

1,438

Steam and Chilled Water Capacity, Megawatts Thermal Equivalent

[2],[3]

1,315

NRG Energy Center Dover [Member]

Nature of Business

Percentage of Ownership

100.00%

Thermal [Member] | Thermal [Member]

Nature of Business

Power Generation Capacity, Megawatts

[2]

20

NRG Yield [Member] | NRG Yield [Member]

Nature of Business

Sale of Stock, Number of Shares Issued in Transaction | shares

28,198,000

NRG Yield LLC | NRG Yield, Inc. [Member]

Nature of Business

Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Voting Interest

44.90%

Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest

53.30%

NRG Yield LLC | NRG [Member]

Nature of Business

Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Voting Interest

55.10%

Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest

46.70%

GenConn Middletown | Conventional Generation [Member]

Nature of Business

Equity Method Investment, Ownership Percentage

50.00%

Power Generation Capacity, Megawatts

[2]

95

GenConn Devon [Member] | Conventional Generation [Member]

Nature of Business

Equity Method Investment, Ownership Percentage

50.00%

Power Generation Capacity, Megawatts

[2]

95

Marsh Landing | Conventional Generation [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

720

El Segundo [Member] | Conventional Generation [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

550

Walnut Creek [Member] | Conventional Generation [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

485

Alpine [Member] | Utility-Scale Solar

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

66

AZ DG Solar Projects [Member] | Distributed Solar [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

5

PFMG DG Solar Projects [Member] | Distributed Solar [Member]

Nature of Business

Percentage of Ownership

51.00%

Power Generation Capacity, Megawatts

[2]

4

Avenal [Member] | Utility-Scale Solar

Nature of Business

Equity Method Investment, Ownership Percentage

50.00%

Power Generation Capacity, Megawatts

[2]

23

Avra Valley | Utility-Scale Solar

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

26

NRG Solar Blythe LLC [Member] | Utility-Scale Solar

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

21

Borrego [Member] | Utility-Scale Solar

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

26

Roadrunner | Utility-Scale Solar

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

20

CVSR [Member] | Utility-Scale Solar

Nature of Business

Equity Method Investment, Ownership Percentage

100.00%

Power Generation Capacity, Megawatts

[2]

250

Kansas South [Member] | Utility-Scale Solar

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

20

TA - High Desert LLC [Member] | Utility-Scale Solar

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

20

Desert Sunlight [Member] | Utility-Scale Solar

Nature of Business

Percentage of Ownership

25.00%

Alta I [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

150

Alta II [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

150

Alta III [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

150

Alta IV [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

102

Alta V [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

168

Alta X [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

[4]

100.00%

Power Generation Capacity, Megawatts

[2],[4]

137

Alta XI [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

[4]

100.00%

Power Generation Capacity, Megawatts

[2],[4]

90

South Trent | Wind Farms [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

101

Spanish Fork [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

75.00%

Power Generation Capacity, Megawatts

[2]

14

Laredo Ridge [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

80

Lookout [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

75.00%

Power Generation Capacity, Megawatts

[2]

29

Odin Wind Farm [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

74.90%

Power Generation Capacity, Megawatts

[2]

15

Taloga [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

130

Wildorado [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

74.90%

Power Generation Capacity, Megawatts

[2]

121

Pinnacle [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

55

San Juan Mesa Wind Project, LLC [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

56.30%

Power Generation Capacity, Megawatts

[2]

68

Sleeping Bear [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

75.00%

Power Generation Capacity, Megawatts

[2]

71

Buffalo Bear [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

100.00%

Power Generation Capacity, Megawatts

[2]

19

Crosswinds [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

74.30%

Power Generation Capacity, Megawatts

[2]

16

Elbow Creek [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

75.00%

Power Generation Capacity, Megawatts

[2]

92

Elkhorn Ridge Wind, LLC [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

50.30%

Power Generation Capacity, Megawatts

[2]

41

Forward [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

75.00%

Power Generation Capacity, Megawatts

[2]

22

Goat Wind [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

74.90%

Power Generation Capacity, Megawatts

[2]

113

Hardin [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

74.30%

Power Generation Capacity, Megawatts

[2]

11

Spring Canyon II [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

90.10%

Power Generation Capacity, Megawatts

[2],[4]

29

Spring Canyon III [Member] | Wind Farms [Member]

Nature of Business

Percentage of Ownership

90.10%

Power Generation Capacity, Megawatts

[2],[4]

25

NRG RPV Holdco [Member]

Nature of Business

Power Generation Capacity, Megawatts

43

NRG DGPV Holdco [Member]

Nature of Business

Power Generation Capacity, Megawatts

52

NRG Energy Center Dover [Member] | Thermal [Member]

Nature of Business

Power Generation Capacity, Megawatts

[2]

103

November 2015 Drop Down Assets [Member]

Nature of Business

Business Acquisition, Consideration Transferred, Working Capital | $

$ 2

Business Acquisition, Percentage of Voting Interests Acquired

75.00%

Payments to Acquire Businesses, Gross | $

$ 207

$ 209

November 2015 Drop Down Assets [Member] | Wind Farms [Member]

Nature of Business

Power Generation Capacity, Megawatts

[2]

814

January 2015 Drop Down Assets [Member]

Nature of Business

Business Acquisitions, Purchase Price | $

$ 489

Business Acquisition, Consideration Transferred, Working Capital | $

$ 9

CVSR [Member]

Nature of Business

Business Acquisition, Percentage of Voting Interests Acquired

51.05%

Payments to Acquire Businesses, Gross | $

$ 78.5

Southern California Edison [Member] | Desert Sunlight [Member] | Utility-Scale Solar

Nature of Business

Power Generation Capacity, Megawatts

[2]

63

Pacific Gas and Electric [Member] | Desert Sunlight [Member] | Utility-Scale Solar

Nature of Business

Power Generation Capacity, Megawatts

[2]

75

Common Class D [Member] | NRG Yield LLC

Nature of Business

Sale of Stock, Percentage of Ownership after Transaction

100.00%

Common Class A [Member] | NRG Yield LLC

Nature of Business

Sale of Stock, Percentage of Ownership after Transaction

100.00%

Common Class C [Member]

Nature of Business

Proceeds from the issuance of common stock | $

$ 599

Financial Institutions [Member] | November 2015 Drop Down Assets [Member]

Nature of Business

Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value | $

$ 159

[1]

(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

[2]

Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2016.

[3]

For thermal energy, net capacity represents MWt for steam or chilled water and excludes 134 MWt available under the right-to-use provisions contained in agreements between two of the Company's thermal facilities and certain of its customers.

[4]

Projects are part of tax equity arrangements

Summary of Significant Accoun33

Summary of Significant Accounting Policies (Details) - USD ($) $ / shares in Units, $ in Millions

Sep. 02, 2016

Feb. 19, 2016

Nov. 03, 2015

Sep. 30, 2016

Jun. 30, 2016

Mar. 31, 2016

Sep. 30, 2015

Sep. 30, 2016

Sep. 30, 2015

Dec. 31, 2015

Summary of Significant Accounting Policies [Line Items]

Accumulated Depreciation, Depletion and Amortization, Property, Plant, and Equipment

$ 1,002

$ 1,002

$ 782

Finite-Lived Intangible Assets, Accumulated Amortization

151

151

93

Stockholders' Equity Attributable to Noncontrolling Interest

(622)

(622)

$ (897)

Capital contributions from tax equity investors, net of distributions

7

$ 123

[1]

Less: Pre-acquisition net income (loss) of Drop Down Assets

6

$ (2)

[2]

10

(6)

[2],[3]

Comprehensive income

$ 30

$ 2

16

32

Yield LLC distributions to NRG

(59)

Payments of Capital Distribution

$ (122)

$ (52)

[1]

Dividends Payable, Date Declared

Nov. 2, 2016

Common Stock, Dividends, Per Share, Declared

$ 0.25

Dividends Payable, Date to be Paid

Dec. 15, 2016

Dividends Payable, Date of Record

Dec. 1, 2016

November 2015 Drop Down Assets [Member]

Summary of Significant Accounting Policies [Line Items]

Business Acquisition, Consideration Transferred, Working Capital

$ 2

Payments to Acquire Businesses, Gross

$ (207)

$ (209)

CVSR [Member]

Summary of Significant Accounting Policies [Line Items]

Payments to Acquire Businesses, Gross

$ (78.5)

Financial Institutions [Member]

Summary of Significant Accounting Policies [Line Items]

Capital contributions from tax equity investors, net of distributions

$ 7

Common Class B [Member]

Summary of Significant Accounting Policies [Line Items]

Distribution Made to Limited Liability Company (LLC) Member, Distributions Paid, Per Unit

$ 0.24

$ 0.23

$ 0.225

Common Class D [Member]

Summary of Significant Accounting Policies [Line Items]

Distribution Made to Limited Liability Company (LLC) Member, Distributions Paid, Per Unit

$ 240,000

$ 230,000

$ 0.225

Drop Down Assets [Member]

Summary of Significant Accounting Policies [Line Items]

Payments of Capital Distribution

$ (172)

[1]

(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

[2]

a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

[3]

(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Business Acquisitions Busines34

Business Acquisitions Business Acquisitions - CVSR (Details) - USD ($) $ in Millions		Sep. 02, 2016	Sep. 30, 2016	Sep. 01, 2016	Aug. 31, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage					48.95%
Current assets			$ 531			$ 416
Property, Plant and Equipment, Net			5,711			5,878
Total Assets			8,482			8,689
Total Liabilities			6,014			5,951
Accumulated other comprehensive loss			(48)			(27)
Debt Issuance Costs, Net			64			$ 63
CVSR [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired				51.05%
Payments to Acquire Businesses, Gross		$ 78.5
Business Combination, Long-term Debt				$ 496
Business Combination, Indemnification Assets, Amount as of Acquisition Date				67
Current assets				95
Property, Plant and Equipment, Net				826
Non-current assets				13
Total Assets				934
Long-term Debt and Capital Lease Obligations, Including Current Maturities	[1]			966
Other Liabilities				12
Total Liabilities				978
Net liabilities assumed				44
Accumulated other comprehensive loss				(25)
Historical Net Liabilities Assumed				(19)
Debt Issuance Costs, Net				$ 5
Business Combination, Pro Forma Information, Revenue of Acquiree since Acquisition Date, Actual			9
Business Combination, Pro Forma Information, Earnings or Loss of Acquiree since Acquisition Date, Actual			$ 4
[1]	(a) Net of deferred financing costs of $5 million.

Business Acquisitions Busines35

Business Acquisitions Business Acquisitions - November 2015 Drop Down (Details)		Feb. 19, 2016USD ($)	Nov. 03, 2015USD ($)	Sep. 30, 2016MW	Nov. 02, 2015USD ($)MW
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts | MW	[1]			4,686
November 2015 Drop Down Assets [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired					75.00%
Number of Facilities					12
Payments to Acquire Businesses, Gross		$ 207,000,000	$ 209,000,000
Business Combination, Long-term Debt			193,000,000
Business Acquisition, Consideration Transferred, Working Capital		$ 2,000,000
Financial Institutions [Member] | November 2015 Drop Down Assets [Member]
Business Acquisition [Line Items]
Business Combination, Acquisition of Less than 100 Percent, Noncontrolling Interest, Fair Value			$ 159,000,000
Taxable Income Allocation, Pre-Flip			99.00%
Taxable Income Allocation, Post-Flip			8.53%
Post-Flip Point [Member] | November 2015 Drop Down Assets [Member]
Business Acquisition [Line Items]
Percentage of Cash Available for Distributions			68.60%
Pre-Flip Point [Member] | November 2015 Drop Down Assets [Member]
Business Acquisition [Line Items]
Percentage of Cash Available for Distributions			75.00%
Pre-determined Date Through Flip Point If Flip Has Not Occured [Member] | Financial Institutions [Member] | November 2015 Drop Down Assets [Member]
Business Acquisition [Line Items]
Percentage of Cash Available for Distributions			100.00%
Wind Farms [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts | MW	[1]			1,999
Wind Farms [Member] | November 2015 Drop Down Assets [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts | MW	[1]				814
[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2016.

Business Acquisitions Busines36

Business Acquisitions Business Acquisitions - Desert Sunlight/Spring Canyon/Fuel Cell (Details)		Jun. 30, 2015USD ($)	May 08, 2015	Apr. 30, 2015	Sep. 30, 2016MW	Aug. 31, 2016	Jun. 29, 2015USD ($)	May 07, 2015
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage						48.95%
Power Generation Capacity, Megawatts	[1]				4,686
Utility-Scale Solar [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]				610
Wind Farms [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]				1,999
Wind Farms [Member] | Spring Canyon [Member]
Business Acquisition [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired								90.10%
Wind Farms [Member] | Spring Canyon II [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts					32
Wind Farms [Member] | Spring Canyon III [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts					28
Thermal [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]				1,438
Desert Sunlight [Member]
Business Acquisition [Line Items]
Number of Facilities | $							2
Power Generation Capacity, Megawatts					550
Payments to Acquire Equity Method Investments | $		$ 285,000,000
Desert Sunlight [Member] | Utility-Scale Solar [Member]
Business Acquisition [Line Items]
Equity Method Investment, Ownership Percentage					25.00%
UB Fuel Cell [Member] | Thermal [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts					1.4
Supply Commitment [Member] | Spring Canyon [Member]
Business Acquisition [Line Items]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life			24 years
Supply Commitment [Member] | UB Fuel Cell [Member]
Business Acquisition [Line Items]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life				12 years
Southern California Edison [Member] | Supply Commitment [Member] | Desert Sunlight [Member]
Business Acquisition [Line Items]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life		20 years
Pacific Gas and Electric [Member] | Supply Commitment [Member] | Desert Sunlight [Member]
Business Acquisition [Line Items]
Acquired Finite-lived Intangible Assets, Weighted Average Useful Life		25 years
[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2016.

Business Acquisitions Busines37

Business Acquisitions Business Acquisitions - January 2015 Drop Downs (Details) $ in Millions		Jan. 02, 2015USD ($)	Sep. 30, 2016MW
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]		4,686
January 2015 Drop Down Assets [Member]
Business Acquisition [Line Items]
Payment to NRG for acquired January 2015 Drop Down Assets | $		$ 489
Business Acquisition, Consideration Transferred, Working Capital | $		9
Business Combination, Consideration Transferred, Liabilities Incurred | $		737
Business Combination, Separately Recognized Transactions, Net Gains and Losses | $		61
Accumulated Other Comprehensive Income (Loss), before Tax | $		$ 23
Wind Farms [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]		1,999
Conventional Generation [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]		1,945
Laredo Ridge [Member] | Wind Farms [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]		80
Buffalo Bear [Member] | Wind Farms [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]		19
Taloga [Member] | Wind Farms [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]		130
Pinnacle [Member] | Wind Farms [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]		55
Walnut Creek [Member] | Conventional Generation [Member]
Business Acquisition [Line Items]
Power Generation Capacity, Megawatts	[1]		485
[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2016.

Variable Interest Entities Vari

Variable Interest Entities Variable Interest Entities - Consolidated Entities (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Other Assets	$ 2,240	$ 2,395
Property, Plant and Equipment, Net	5,711	5,878
Total Assets	8,482	8,689
Liabilities	6,014	$ 5,951
November 2015 Drop Down Assets [Member]
Schedule of Equity Method Investments [Line Items]
Other Assets	189
Property, Plant and Equipment, Net	635
Intangible Assets	2
Total Assets	826
Liabilities	225
Noncontrolling Interest in Variable Interest Entity	209
Net Assets	392
Alta X and XI TE Holdco [Member]
Schedule of Equity Method Investments [Line Items]
Other Assets	19
Property, Plant and Equipment, Net	466
Intangible Assets	278
Total Assets	763
Liabilities	9
Noncontrolling Interest in Variable Interest Entity	118
Net Assets	636
Spring Canyon [Member]
Schedule of Equity Method Investments [Line Items]
Other Assets	4
Property, Plant and Equipment, Net	101
Intangible Assets	0
Total Assets	105
Liabilities	6
Noncontrolling Interest in Variable Interest Entity	69
Net Assets	$ 30

Variable Interest Entities Va39

Variable Interest Entities Variable Interest Entities - DGPV (Details) $ in Millions		Feb. 29, 2016	May 08, 2015generatingunitMW	Sep. 30, 2016USD ($)MW	Dec. 31, 2015USD ($)
Schedule of Equity Method Investments [Line Items]
Power Generation Capacity, Megawatts | MW	[1]			4,686
Equity investments in affiliates				$ 690	$ 697
NRG DGPV Holdco [Member]
Schedule of Equity Method Investments [Line Items]
Equity investments in affiliates				77
NRG DGPV Fund 1 [Member]
Schedule of Equity Method Investments [Line Items]
Remaining Lease Term		18 years
Tax Equity Financed Portfolio of Leases - Commercial PV [Member] | NRG DGPV Fund 1 [Member]
Schedule of Equity Method Investments [Line Items]
Number of Solar Leases in Portfolio | generatingunit			12
Power Generation Capacity, Megawatts | MW			37
Remaining Lease Term			19 years
Tax Equity Financed Portfolio of Leases - Community Solar [Member] | NRG DGPV Fund 1 [Member]
Schedule of Equity Method Investments [Line Items]
Number of Solar Leases in Portfolio | generatingunit			10
Power Generation Capacity, Megawatts | MW			8
Remaining Lease Term			20 years
Maximum [Member] | Tax Equity Financed Portfolio of Leases [Member] | NRG DGPV Fund 1 [Member]
Schedule of Equity Method Investments [Line Items]
Equity investments in affiliates				100
Maximum [Member] | Tax Equity Financed Portfolio of Leases [Member] | NRG DGPV Fund 2 [Member]
Schedule of Equity Method Investments [Line Items]
Equity investments in affiliates				$ 50
[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2016.

Variable Interest Entities Va40

Variable Interest Entities Variable Interest Entities - RPV (Details) $ in Millions		9 Months Ended
		Sep. 30, 2016USD ($)generatingunitMW	Aug. 05, 2016USD ($)	Dec. 31, 2015USD ($)
Schedule of Equity Method Investments [Line Items]
Power Generation Capacity, Megawatts | MW	[1]	4,686
Equity investments in affiliates		$ 690		$ 697
NRG RPV Holdco [Member]
Schedule of Equity Method Investments [Line Items]
Equity investments in affiliates		$ 70
Existing Portfolio of Leases [Member] | NRG RPV Holdco [Member]
Schedule of Equity Method Investments [Line Items]
Number of Solar Leases in Portfolio | generatingunit		2,000
Power Generation Capacity, Megawatts | MW		15
Remaining Lease Term		17 years
Tax Equity Financed Portfolio of Leases [Member] | NRG RPV Holdco [Member]
Schedule of Equity Method Investments [Line Items]
Number of Solar Leases in Portfolio | generatingunit		5,400
Power Generation Capacity, Megawatts | MW		28
Capital Contributions From Partners in Equity Method Investment		$ 57
Minimum [Member] | Tax Equity Financed Portfolio of Leases [Member] | NRG RPV Holdco [Member]
Schedule of Equity Method Investments [Line Items]
Remaining Lease Term		17 years
Maximum [Member] | Tax Equity Financed Portfolio of Leases [Member] | NRG RPV Holdco [Member]
Schedule of Equity Method Investments [Line Items]
Remaining Lease Term		20 years
Equity investments in affiliates		$ 150
Capital Contributions From Partners in Equity Method Investment		$ 60	$ 100
[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2016.

Variable Interest Entities Va41

Variable Interest Entities Variable Interest Entities - GenConn (Details) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2016USD ($)facilityMW	Sep. 30, 2015USD ($)		Sep. 30, 2016USD ($)facilityMW	Sep. 30, 2015USD ($)		Aug. 31, 2016	Dec. 31, 2015USD ($)
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage								48.95%
Power Generation Capacity, Megawatts | MW	[1]	4,686			4,686
Equity investments in affiliates		$ 690			$ 690				$ 697
Total operating revenues		272	$ 256	[2],[3]	789	$ 729	[2],[3]
Operating Income (Loss)		117	101	[2],[3]	317	250	[2],[3]
Net Income (Loss)		47	32	[2],[3],[4]	111	53	[2],[3],[4]
Current assets		531			531				416
Current liabilities		459			459				489
Non-current liabilities		$ 5,555			$ 5,555				5,462
GCE Holding LLC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage		50.00%			50.00%
Equity investments in affiliates		$ 106			$ 106
Total operating revenues		18	21		54	61
Operating Income (Loss)		9	9		28	29
Net Income (Loss)		7	$ 6		20	$ 20
Current assets		29			29				36
Non-current assets		403			403				416
Current liabilities		12			12				16
Non-current liabilities		$ 208			$ 208				$ 215
Gen Conn Energy LLC [Member]
Schedule of Equity Method Investments [Line Items]
Power Generation Units, Number | facility		2			2
Power Generation Capacity, Megawatts | MW		190			190
[1]	Net capacity represents the maximum, or rated, generating capacity of the facility multiplied by the Company's percentage ownership in the facility as of September 30, 2016.
[2]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[3]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[4]	a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Fair Value of Financial Instr42

Fair Value of Financial Instruments Fair Value of Financial Instruments - Balance Sheet Grouping (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Reported Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Financing Receivable, Net	$ 35	$ 47
Long-term Debt and Capital Lease Obligations, Including Current Maturities	5,704	5,656
Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Financing Receivable, Net	35	47
Long-term Debt and Capital Lease Obligations, Including Current Maturities	5,729	5,538
Fair Value, Inputs, Level 2 [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities	1,478	978
Fair Value, Inputs, Level 3 [Member] | Estimate of Fair Value Measurement [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term Debt and Capital Lease Obligations, Including Current Maturities	$ 4,251	$ 4,560

Fair Value of Financial Instr43

Fair Value of Financial Instruments Fair Value of Financial Instruments - Recurring Fair Value (Details) - USD ($)		Sep. 30, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset		$ 1,000,000
Derivative Liability, Fair Value, Gross Liability		139,000,000	$ 100,000,000
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	[1]	1,000,000	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net		0	0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	[1]	139,000,000	100,000,000
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets (Liabilities), at Fair Value, Net		0	0
Commodity Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Asset, Fair Value, Gross Asset	[1]	1,000,000	0
Derivative Liability, Fair Value, Gross Liability	[1]	1,000,000	2,000,000
Interest Rate Contract [Member] | Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Liability, Fair Value, Gross Liability	[1]	$ 138,000,000	$ 98,000,000
[1]	(a) There were no derivative assets or liabilities classified as Level 1 or Level 3 as of September 30, 2016, and December 31, 2015.

Fair Value of Financial Instr44

Fair Value of Financial Instruments Fair Value of Financial Instruments - Credit Risk and Derivative FV Measurements (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value Assets, Valuation Techniques, Impact of Credit Reserve to Fair Value	$ 4
Estimated Counterparty Credit Risk Exposure to Certain Counterparties, Period	5 years
Concentration Risk, Credit Risk, Financial Instrument, Maximum Exposure	$ 2,600
Gain (Loss) on Derivative Instruments [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value Assets, Valuation Techniques, Impact of Credit Reserve to Fair Value	3
Interest Expense [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Fair Value Assets, Valuation Techniques, Impact of Credit Reserve to Fair Value	$ 1

Accounting for Derivative Ins45

Accounting for Derivative Instruments and Hedging Activities Accounting for Derivative Instruments and Hedging Activities - FV of Derivatives (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 1
Derivative Liability, Fair Value, Gross Liability	139	$ 100
Derivative, Collateral, Right to Reclaim Cash	0	0
Derivative, Collateral, Obligation to Return Cash	0	0
Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0
Derivative Liability, Fair Value, Gross Liability	123	90
Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1
Derivative Liability, Fair Value, Gross Liability	16	10
Interest Rate Contract Current [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0
Derivative Liability, Fair Value, Gross Liability	29	34
Interest Rate Contract Current [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0
Derivative Liability, Fair Value, Gross Liability	2	3
Interest Rate Contract Non Current [Member] | Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0
Derivative Liability, Fair Value, Gross Liability	94	56
Interest Rate Contract Non Current [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0
Derivative Liability, Fair Value, Gross Liability	13	5
Commodity Contract Current [Member] | Not Designated as Hedging Instrument [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	1
Derivative Liability, Fair Value, Gross Liability	1	2
Interest [Member] | United States of America, Dollars
Derivatives, Fair Value [Line Items]
Derivative, Notional Amount	1,875	1,991
Natural Gas [Member] | MMbtu [Member]
Derivatives, Fair Value [Line Items]
Derivative, Notional Amount	$ 3	$ 4

Accounting for Derivative Ins46

Accounting for Derivative Instruments and Hedging Activities Accounting for Derivative Instruments and Hedging Activities - AOCI (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Derivative [Line Items]
Accumulated Other Comprehensive Loss, Net of Tax	$ (119)	$ (104)	$ (119)	$ (104)	$ (140)	$ (83)	$ (73)	$ (76)
Accumulated Other Comprehensive Loss, Cumulative Change in Loss from Cash Flow Hedges, Tax Amount	(29)	(19)	(29)	(19)
Mark-to-market of cash flow hedge accounting contracts	17	(36)	(46)	(40)
Losses expected to be realized from OCL during the next 12 months, net of income tax benefit of $4			16
Losses expected to be realized from OCL during the next 12 months, Tax Amount	(4)		(4)
Gain (Loss) on Cash Flow Hedge Ineffectiveness, Net			0	0
Reclassification out of Accumulated Other Comprehensive Income [Member]
Derivative [Line Items]
Reclassified from accumulated OCL to income due to realization of previously deferred amounts	4	5	10	12
Noncontrolling Interest [Member]
Derivative [Line Items]
Accumulated Other Comprehensive Loss, Net of Tax	(71)	(72)	(71)	(72)
Successor [Member]
Derivative [Line Items]
Accumulated Other Comprehensive Loss, Net of Tax	$ (48)	$ (32)	$ (48)	$ (32)

Accounting for Derivative Ins47

Accounting for Derivative Instruments and Hedging Activities Accounting for Derivative Instruments and Hedging Activities - Impact to Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Interest Rate Contract [Member] | Interest Expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized Gain (Loss) on Derivatives	$ 2	$ (6)	$ (7)	$ 13
Commodity Contract [Member] | Sales [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Unrealized Gain (Loss) on Derivatives		$ (2)		$ 1

Long-term Debt Long-term Debt -

Long-term Debt Long-term Debt - Debt Table (Details) - USD ($) $ in Thousands		9 Months Ended
		Sep. 30, 2016	Jul. 15, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Debt		$ 5,704,000		$ 5,656,000
Current portion of long-term debt		281,000		264,000
Debt Issuance Costs, Net		64,000		63,000
Long-term Debt, Excluding Current Maturities		5,359,000		5,329,000
3.5% Convertible Notes due 2019 [Member]
Debt Instrument [Line Items]
Debt	[1]	$ 334,000		330,000
Debt Instrument, Interest Rate, Stated Percentage	[2]	3.50%
Debt Instrument, Unamortized Discount		$ 11,000		15,000
3.25% Convertible Notes due 2020 [Member]
Debt Instrument [Line Items]
Debt	[3]	$ 270,000		266,000
Debt Instrument, Interest Rate, Stated Percentage	[2]	3.25%
Debt Instrument, Unamortized Discount		$ 17,000		21,000
5.375% Senior Notes due in 2024 [Member]
Debt Instrument [Line Items]
Senior Notes		$ 500,000		500,000
Debt Instrument, Interest Rate, Stated Percentage	[2]	5.375%
5.00% Senior Notes due in 2026 [Member]
Debt Instrument [Line Items]
Senior Notes		$ 350,000		0
Debt Instrument, Interest Rate, Stated Percentage	[2]	5.00%
NRG Yield Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Debt	[4]	$ 0		306,000
Debt Instrument, Description of Variable Rate Basis	[2]	1 month LIBOR
Debt Instrument, Basis Spread on Variable Rate	[4]	2.75%
Alta Wind I, lease financing arrangement, due 2034 [Member]
Debt Instrument [Line Items]
Debt		$ 245,000		252,000
Debt Instrument, Interest Rate, Stated Percentage	[2]	7.015%
Alta Wind II, lease financing arrangement, due 2034 [Member]
Debt Instrument [Line Items]
Debt		$ 194,000		198,000
Debt Instrument, Interest Rate, Stated Percentage	[2]	5.696%
Alta Wind III, lease financing arrangement, due 2034 [Member]
Debt Instrument [Line Items]
Debt		$ 201,000		206,000
Debt Instrument, Interest Rate, Stated Percentage	[2]	6.067%
Alta Wind IV, lease financing arrangement, due 2034 [Member]
Debt Instrument [Line Items]
Debt		$ 130,000		133,000
Debt Instrument, Interest Rate, Stated Percentage	[2]	5.938%
Alta Wind V, lease financing arrangement, due 2035 [Member]
Debt Instrument [Line Items]
Debt		$ 208,000		213,000
Debt Instrument, Interest Rate, Stated Percentage	[2]	6.071%
Alta Realty Investments, due 2031 [Member]
Debt Instrument [Line Items]
Debt		$ 32,000		33,000
Debt Instrument, Interest Rate, Stated Percentage	[2]	7.00%
Alta Wind Asset Management, due 2031 [Member]
Debt Instrument [Line Items]
Debt		$ 18,000		19,000
Debt Instrument, Description of Variable Rate Basis	[2]	3 month LIBOR
Debt Instrument, Basis Spread on Variable Rate		2.375%
West Holdings Credit Agreement [Member]
Debt Instrument [Line Items]
Debt		$ 443,000		485,000
Debt Instrument, Description of Variable Rate Basis	[2]	3 month LIBOR
West Holdings Credit Agreement due 2023 Tranche A [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		1.625%
Marsh Landing Term Loan Facility [Member]
Debt Instrument [Line Items]
Debt		$ 385,000		418,000
Walnut Creek Energy, LLC, due in 2023 [Member]
Debt Instrument [Line Items]
Debt		$ 322,000		351,000
Debt Instrument, Description of Variable Rate Basis	[2]	1 month LIBOR
Debt Instrument, Basis Spread on Variable Rate		1.625%
Tapestry Wind LLC due in 2021 [Member]
Debt Instrument [Line Items]
Debt		$ 175,000		181,000
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		1.625%
Viento Funding II, Inc., due in 2023 [Member]
Debt Instrument [Line Items]
Debt		$ 183,000		189,000
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		2.75%
NRG Energy Center Minneapolis LLC Senior Secured Notes [Member]
Debt Instrument [Line Items]
Debt		$ 98,000		108,000
Laredo Ridge Wind, LLC, due in 2026 [Member]
Debt Instrument [Line Items]
Debt		$ 101,000		104,000
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		1.875%
South Trent Financing Agreement [Member]
Debt Instrument [Line Items]
Debt		$ 58,000		62,000
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		1.625%
Avra Valley Financing Agreement [Member]
Debt Instrument [Line Items]
Debt		$ 57,000		60,000
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		1.75%
High Desert Facility [Member]
Debt Instrument [Line Items]
Debt		$ 51,000		52,000
WCEP Holdings, LLC, due in 2023 [Member]
Debt Instrument [Line Items]
Debt		$ 46,000		46,000
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		3.00%
Other Debt [Member]
Debt Instrument [Line Items]
Debt		$ 0		2,000
Letters of Credit Outstanding, Amount		0
Roadrunner Financing Agreement [Member]
Debt Instrument [Line Items]
Debt		$ 37,000		40,000
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		1.625%
Kansas South Facility, due 2031 [Member]
Debt Instrument [Line Items]
Debt		$ 31,000		33,000
Debt Instrument, Description of Variable Rate Basis	[2]	6-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		2.00%
NRG Solar Blythe LLC Credit Agreement Due 2028 [Member]
Debt Instrument [Line Items]
Debt		$ 20,000		21,000
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		1.625%
PFMG Financing Agreement [Member]
Debt Instrument [Line Items]
Debt		$ 28,000		29,000
Debt Instrument, Interest Rate, Stated Percentage	[2]	6.00%
Project [Domain]
Debt Instrument [Line Items]
Debt		$ 4,250,000		4,254,000
West Holdings Credit Agreement due 2023 Tranche B [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate		2.25%
Marsh Landing Tranche A due December 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis	[2]	1 month LIBOR
Debt Instrument, Basis Spread on Variable Rate		1.75%
Marsh Landing Tranche B due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis	[2]	1 month LIBOR
Debt Instrument, Basis Spread on Variable Rate		1.875%
Alpine Financing Agreement, due 2022 [Member]
Debt Instrument [Line Items]
Debt		$ 147,000		154,000
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		1.75%
NRG Energy Center Minneapolis LLC Senior Secured Notes, due 2017 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.95%
NRG Energy Center Minneapolis LLC Senior Secured Notes, due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		7.25%
Borrego Financing Agreement, due 2024 [Member]
Debt Instrument [Line Items]
Debt		$ 70,000		72,000
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		2.50%
CVSR Financing Agreement [Member]
Debt Instrument [Line Items]
Debt		$ 771,000		793,000
Debt Instrument, Interest Rate, Stated Percentage			4.68%
CVSR Holdco due 2037 [Member]
Debt Instrument [Line Items]
Debt		$ 199,000		$ 0
Debt Instrument, Interest Rate, Stated Percentage		4.68%
Borrego Financing Agreement, due 2038 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.65%
High Desert Facility, due 2033 [Member]
Debt Instrument [Line Items]
Debt Instrument, Description of Variable Rate Basis	[2]	3-Month LIBOR
Debt Instrument, Basis Spread on Variable Rate		2.50%
TA - High Desert, due 2023 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		5.15%
Minimum [Member] | CVSR Financing Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		2.339%
Maximum [Member] | CVSR Financing Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage		3.775%
Letter of Credit [Member] | NRG Yield Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		$ 64,000
Letter of Credit [Member] | Alta Wind I, lease financing arrangement, due 2034 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		16,000
Letter of Credit [Member] | Alta Wind II, lease financing arrangement, due 2034 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		23,000
Letter of Credit [Member] | Alta Wind III, lease financing arrangement, due 2034 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		23,000
Letter of Credit [Member] | Alta Wind IV, lease financing arrangement, due 2034 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		16,000
Letter of Credit [Member] | Alta Wind V, lease financing arrangement, due 2035 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		26,000
Letter of Credit [Member] | Alta Realty Investments, due 2031 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		0
Letter of Credit [Member] | Alta Wind Asset Management, due 2031 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		0
Letter of Credit [Member] | West Holdings Credit Agreement [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		82,000
Letter of Credit [Member] | Marsh Landing Term Loan Facility [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		33,000
Letter of Credit [Member] | Walnut Creek Energy, LLC, due in 2023 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		49,000
Letter of Credit [Member] | Tapestry Wind LLC due in 2021 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		20,000
Letter of Credit [Member] | Viento Funding II, Inc., due in 2023 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		27,000
Letter of Credit [Member] | NRG Energy Center Minneapolis LLC Senior Secured Notes [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		0
Letter of Credit [Member] | Laredo Ridge Wind, LLC, due in 2026 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		10,000
Letter of Credit [Member] | South Trent Financing Agreement [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		10,000
Letter of Credit [Member] | Avra Valley Financing Agreement [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		3,000
Letter of Credit [Member] | High Desert Facility [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		8,000
Letter of Credit [Member] | WCEP Holdings LLC [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		0
Letter of Credit [Member] | Roadrunner Financing Agreement [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		5,000
Letter of Credit [Member] | Kansas South Facility, due 2031 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		4,000
Letter of Credit [Member] | NRG Solar Blythe LLC Credit Agreement Due 2028 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		6,000
Letter of Credit [Member] | PFMG Financing Agreement [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		0
Letter of Credit [Member] | Alpine Financing Agreement, due 2022 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		37,000
Letter of Credit [Member] | Borrego Financing Agreement, due 2024 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		5,000
Letter of Credit [Member] | CVSR Financing Agreement [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		0
Letter of Credit [Member] | CVSR Holdco due 2037 [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount		$ 13,000
[1]	Net of discount of $11 million and $15 million as of September 30, 2016, and December 31, 2015, respectively.
[2]	As of September 30, 2016, L+ equals 3 month LIBOR plus x%, except for the Alpine term loan, Marsh Landing term loan, Walnut Creek term loan, and NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility, where L+ equals 1 month LIBOR plus x% and Kansas South and Viento, where L+ equals 6 month LIBOR plus x%
[3]	Net of discount of $17 million and $21 million as of September 30, 2016, and December 31, 2015, respectively
[4]	Applicable rate is determined by the borrower leverage ratio, as defined in the credit agreement.

Long-term Debt Long-term Debt49

Long-term Debt Long-term Debt - Debt Disclosures(Details) - USD ($) $ in Millions		Oct. 31, 2016	Aug. 24, 2016	Aug. 18, 2016	Jul. 15, 2016	Jul. 31, 2016	Sep. 30, 2016	Sep. 01, 2016	Aug. 31, 2016
Debt Instrument [Line Items]
Equity Method Investment, Ownership Percentage									48.95%
3.5% Convertible Notes due 2019 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	[1]						3.50%
NRG Yield Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt							$ 60
Repayments of Debt			$ 193			$ 28	366
Line of Credit Facility, Fair Value of Amount Outstanding							$ 0
CVSR Financing Agreement [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt					$ 200
Debt Instrument, Interest Rate, Stated Percentage					4.68%
Proceeds from Debt, Net of Issuance Costs					$ 97.5
5.00% Senior Notes due in 2026 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	[1]						5.00%
Proceeds from Issuance of Unsecured Debt				$ 350
3.25% Convertible Notes due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Interest Rate, Stated Percentage	[1]						3.25%
Letter of Credit [Member] | NRG Yield Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount							$ 64
Letter of Credit [Member] | CVSR Financing Agreement [Member]
Debt Instrument [Line Items]
Letters of Credit Outstanding, Amount							$ 0
Subsequent Event [Member] | NRG Energy Center Minneapolis Series D Notes [Member]
Debt Instrument [Line Items]
Proceeds from Issuance of Debt		$ 125
Debt Instrument, Interest Rate, Stated Percentage		3.55%
Utility-Scale Solar [Member] | CVSR [Member]
Debt Instrument [Line Items]
Equity Method Investment, Ownership Percentage							100.00%
CVSR [Member]
Debt Instrument [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired								51.05%
Business Combination, Long-term Debt								$ 496
[1]	As of September 30, 2016, L+ equals 3 month LIBOR plus x%, except for the Alpine term loan, Marsh Landing term loan, Walnut Creek term loan, and NRG Yield LLC and NRG Yield Operating LLC Revolving Credit Facility, where L+ equals 1 month LIBOR plus x% and Kansas South and Viento, where L+ equals 6 month LIBOR plus x%

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net Income (Loss) Available to Common Stockholders, Basic		$ 33	$ 17	$ 70	$ 22
Common Class A [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net Income (Loss) Available to Common Stockholders, Basic	[1]	$ 12	$ 6	$ 25	$ 10
Weighted average number of common shares outstanding — basic	[1]	35,000,000	35,000,000	35,000,000	35,000,000
Earnings per weighted average common share — basic	[1]	$ 0.34	$ 0.18	$ 0.72	$ 0.28
Net Income (Loss) Available to Common Stockholders, Diluted	[1]	$ 15	$ 6	$ 34	$ 10
Weighted average number of common shares outstanding — diluted	[1]	49,000,000	35,000,000	49,000,000	35,000,000
Earnings per weighted average common share — diluted	[1]	$ 0.30	$ 0.18	$ 0.68	$ 0.28
Common Class C [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Net Income (Loss) Available to Common Stockholders, Basic	[1]	$ 21	$ 11	$ 45	$ 12
Weighted average number of common shares outstanding — basic	[1]	63,000,000	63,000,000	63,000,000	44,000,000
Earnings per weighted average common share — basic	[1]	$ 0.34	$ 0.18	$ 0.72	$ 0.28
Net Income (Loss) Available to Common Stockholders, Diluted	[1]	$ 24	$ 11	$ 45	$ 12
Weighted average number of common shares outstanding — diluted	[1]	73,000,000	63,000,000	63,000,000	44,000,000
Earnings per weighted average common share — diluted	[1]	$ 0.32	$ 0.18	$ 0.72	$ 0.28
3.5% Convertible Notes due 2019 [Member] | Common Class A [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount			15	15,000,000	15,000,000
3.25% Convertible Notes due 2020 [Member] | Common Class C [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount			10,000,000	10,000,000	4,000,000
[1]	(a) Net income attributable to NRG Yield, Inc. and basic and diluted earnings per share might not recalculate due to presenting values in millions rather than whole dollars.

Segment Reporting (Details)

Segment Reporting (Details) - USD ($) $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015		Sep. 30, 2016	Sep. 30, 2015		Dec. 31, 2015
Segment Reporting
Operating revenues		$ 272	$ 256	[1],[2]	$ 789	$ 729	[1],[2]
Cost of operations		76	82	[2]	238	246	[2]
Depreciation and amortization		75	69	[1],[2]	224	222	[1],[2]
General and administrative		4	3	[1],[2]	10	9	[1],[2]
Acquisition-related transaction and integration costs		0	1	[1],[2]	0	2	[1],[2]
Operating Income		117	101	[1],[2]	317	250	[1],[2]
Equity in earnings of unconsolidated affiliates		13	12	[1],[2]	29	19	[1],[2]
Other income, net		1	0	[1]	3	2	[1],[2]
Loss on debt extinguishment		0	(2)	[1],[2]	0	(9)	[1],[2],[3]
Interest expense		(71)	(71)	[1],[2]	(213)	(201)	[1],[2]
Income Before Income Taxes		60	40	[1],[2]	136	61	[1],[2]
Income tax expense		13	8	[2]	25	8	[2]
Net Income		47	32	[1],[2],[4]	111	53	[1],[2],[4]
Total Assets		8,482			8,482			$ 8,689
Conventional Generation
Segment Reporting
Operating revenues		82	86	[2]	246	247	[2]
Cost of operations		14	15	[2]	53	51	[2]
Depreciation and amortization		20	19	[2]	60	61	[2]
General and administrative		0	0	[2]	0	0	[2]
Acquisition-related transaction and integration costs	[2]		0			0
Operating Income		48	52	[2]	133	135	[2]
Equity in earnings of unconsolidated affiliates		3	3	[2]	10	10	[2]
Other income, net		1			1	1	[2]
Loss on debt extinguishment	[2]		0			(7)
Interest expense		(13)	(11)	[2]	(36)	(36)	[2]
Income Before Income Taxes		39	44	[2]	108	103	[2]
Income tax expense		0	0	[2]	0	0
Net Income		39	44	[2]	108	103	[2]
Total Assets		2,001			2,001
Renewables
Segment Reporting
Operating revenues		142	124	[2]	412	347	[2]
Cost of operations		31	36	[2]	98	99	[2]
Depreciation and amortization		50	45	[2]	149	147	[2]
General and administrative		0	0	[2]	0	0	[2]
Acquisition-related transaction and integration costs	[2]		0			0
Operating Income		61	43	[2]	165	101	[2]
Equity in earnings of unconsolidated affiliates		10	9	[2]	19	9	[2]
Other income, net		0			2	1	[2]
Loss on debt extinguishment	[2]		(2)			(2)
Interest expense		(37)	(41)	[2]	(115)	(116)	[2]
Income Before Income Taxes		34	9	[2]	71	(7)	[2]
Income tax expense		0	0	[2]	0	0	[2]
Net Income		34	9	[2]	71	(7)	[2]
Total Assets		5,783			5,783
Thermal [Member]
Segment Reporting
Operating revenues		48	46	[2]	131	135	[2]
Cost of operations		31	31	[2]	87	96	[2]
Depreciation and amortization		5	5	[2]	15	14	[2]
General and administrative		0	0	[2]	0	0	[2]
Acquisition-related transaction and integration costs	[2]		0			0
Operating Income		12	10	[2]	29	25	[2]
Equity in earnings of unconsolidated affiliates		0	0	[2]	0	0	[2]
Other income, net		0			0	0	[2]
Loss on debt extinguishment	[2]		0			0
Interest expense		(2)	(1)	[2]	(5)	(5)	[2]
Income Before Income Taxes		10	9	[2]	24	20	[2]
Income tax expense		0	0	[2]	0	0
Net Income		10	9	[2]	24	20	[2]
Total Assets		427			427
Corporate
Segment Reporting
Operating revenues		0	0	[2]	0	0	[2]
Cost of operations		0	0	[2]	0	0	[2]
Depreciation and amortization		0	0	[2]	0	0	[2]
General and administrative		4	3	[2]	10	9	[2]
Acquisition-related transaction and integration costs	[2]		1			2
Operating Income		(4)	(4)	[2]	(10)	(11)	[2]
Equity in earnings of unconsolidated affiliates		0	0	[2]	0	0	[2]
Other income, net		0			0	0	[2]
Loss on debt extinguishment	[2]		0			0
Interest expense		(19)	(18)	[2]	(57)	(44)	[2]
Income Before Income Taxes		(23)	(22)	[2]	(67)	(55)	[2]
Income tax expense		13	8	[2]	25	8
Net Income		(36)	$ (30)	[2]	(92)	$ (63)	[2]
Total Assets		$ 271			$ 271
[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[3]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[4]	a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Income Taxes (Provision) (Detai

Income Taxes (Provision) (Details) - USD ($) $ in Millions	3 Months Ended			9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015		Sep. 30, 2016	Sep. 30, 2015
Income Tax Expense (Benefit), Continuing Operations [Abstract]
Income before income taxes	$ 60	$ 40	[1],[2]	$ 136	$ 61	[1],[2]
Income tax expense	$ 13	$ 8	[2]	$ 25	$ 8	[2]
Effective income tax rate	21.66667%	20.00%		18.38235%	13.10%
U.S. federal statutory rate (as a percent)				35.00%
[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended			9 Months Ended			12 Months Ended
	Oct. 31, 2016	Sep. 30, 2016	Sep. 30, 2015	[1],[2]	Sep. 30, 2016	Sep. 30, 2015		Dec. 31, 2015
Related Party Transaction
General and administrative		$ 4	$ 3		$ 10	$ 9	[1],[2]
Due to Affiliate, Current		29			29			$ 86
Accounts payable — affiliate		11			11			0
GenOn Energy Services LLC [Member]
Related Party Transaction
Due to Affiliate		1			1			6
NRG Repowering Holdings LLC [Member]
Related Party Transaction
Cost of Natural Gas Purchases					1	4
NRG Yield [Member] | NRG [Member]
Related Party Transaction
Management Services Fee, Increase								0.5
General and administrative					7	5
NRG Yield [Member] | NRG [Member] | Scenario, Plan [Member]
Related Party Transaction
Management Services Fee, Annual					7.5
NRG Yield, Inc. [Member] | NRG [Member]
Related Party Transaction
Due to Affiliate		3			3
Thermal [Member] | NRG [Member]
Related Party Transaction
Related Party Transaction, Expenses from Transactions with Related Party					15
Due to Affiliate		23			23			29
Due to Affiliate, Current		12			12
Accounts payable — affiliate		11			11
NRG Energy Center Dover [Member] | NRG [Member]
Related Party Transaction
Revenue from Related Parties					4
NRG Energy Center Minneapolis LLC [Member] | NRG [Member]
Related Party Transaction
Related Party Transaction, Expenses from Transactions with Related Party					5	6
Marsh Landing [Member] | GenOn Energy Services LLC [Member]
Related Party Transaction
Related Party Transaction, Expenses from Transactions with Related Party					9	11
El Segundo [Member] | NRG El Segundo Operations, Inc. [Member]
Related Party Transaction
Related Party Transaction, Expenses from Transactions with Related Party					4	4
Due to Affiliate		$ 1			1			$ 1
Gen Conn Energy LLC [Member] | NRG [Member]
Related Party Transaction
Related Party Transaction, Expenses from Transactions with Related Party					4	3
CVSR [Member] | NRG Energy Services LLC [Member]
Related Party Transaction
Related Party Transaction, Expenses from Transactions with Related Party					2	4
November 2015 Drop Down Assets [Member] | NRG [Member]
Related Party Transaction
Related Party Transaction, Other Revenues from Transactions with Related Party						17
Elbow Creek [Member] | NRG [Member]
Related Party Transaction
Revenue from Related Parties					6
Operations and Maintenance services [Member] | November 2015 Drop Down Assets [Member] | NRG [Member]
Related Party Transaction
Related Party Transaction, Expenses from Transactions with Related Party					4	3
Support services [Member] | November 2015 Drop Down Assets [Member] | NRG [Member]
Related Party Transaction
Related Party Transaction, Expenses from Transactions with Related Party					$ 2	$ 2
Subsequent Event [Member]
Related Party Transaction
Repayments of Related Party Debt	$ 4
[1]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.
[2]	(a) Retrospectively adjusted as discussed in Note 1, Nature of Business.